Oil Review Middle East Issue 4 2013

ORME 4 2013 Cover_ORMETHREE05COVER.qxd 13/06/2013 10:22 Page 1

Vol 16 Issue Four 2013

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Oil Review Middle East - Volume 16 - Issue Four 2013

UK ÂŁ10, USA $16.50

Gas demand set to surpass oil Iraq to increase production E&P spending forecast to rise Region to dominate petrochemicals sector by 2020 Kuwait - development or deadlock?

LNG project delays worry shipowners

Advanced security for the world’s largest GTL plant

Could shale supply Saudi gas?

A new generation in reservoir characterisation Flow profiling on demand

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Gravity and magnetic data provide an added and critical dimension in oil and gas exploration by delivering a much clearer geological picture than using seismic data alone.

See page 48

al ion r g re cto e th s se 7 9 ing ga 9 rv l & ce 1 e S oi in s

16

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a ye

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Contents Editor’s note

Columns

KUWAIT HAS HAD 17 oil ministers in the past 23 years, with a consequent lack of consistent long-term strategy. Regular attempts during this period to ‘reset’ its oil and gas industry and go for growth have given way to sniping between the emirate’s main political factions, notably the royal family-dominated government and an oppositionist parliament eager to carve out a larger role for itself.

Meanwhile the country’s oil industry - the source of almost all of its wealth has suffered. Doubts over Kuwait’s ability to raise its crude production capacity go back to the beginning of the 2000s. At that time, leaked official documents were reported in the media to have put the country’s actual reserves closer to half the official number, which then stood at just under today’s 101bn barrels. Since then, Kuwait’s oil reserves, its production and the production/reserve ratio, have taken on an enhanced domestic political significance. Doubts about the country’s hydrocarbon industry in general have spread to the wider international oil and gas business, as well as financial industry circles. Peak oil theorists also pounced on ambiguities over the country’s reserves and an inability to deliver on promised production capacity growth. The overall effect has been a trust and branding issue, both for KPC and for its subsidiaries. And erratic project development has done little to improve matters.

Industry news and executives’ calendar

4

Analysis 10

Saudi Arabia Could shale gas be the answer to Saudi Arabia’s long-term conventional gas requirements?

14

Kuwait Major investment and an infusion of know-how and technology are the prime requirements for Kuwait’s energy sector. But political infighting continues to make progress difficult.

Exploration & Production 16

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

Gas 20

LNG

Lynda Davies reports on some worrying developments for shipowners who rely on the LNG sector.

Petrochemicals & Refining 28

Analysis

Cover Image courtsey of: Shell Photographic Services/Shell International Ltd

The region is set to dominate the petrochemicals sector by 2020, according to a new report.

Country Focus 34

Saudi Arabia

The world’s biggest oil producer, Saudi Aramco, is now exploring a whole new business area: power generation.

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

38

Qatar

SMEs will get the chance to supply equipment and services to the Pearl GTL project.

Managing Editor: David Clancy Editorial and Design team: Bob Adams, Hiriyti Bairu, Lizzie Carroll, Andrew Croft, Ranganath GS, Kasturi Gupta, Prashant AP, Genaro Santos, Zsa Tebbit, Nicky Valsamakis, and Ben Watts

Technical Focus

Publisher: Nick Fordham

Innovations

Advertising Sales Director: Pallavi Pandey

Magazine Sales Manager: Camilla Capece Tel: +971 4 448 9260, Fax: +971 4 448 9261, Email: camilla.capece@alaincharles.com For country contacts, see Arabic contents Head Office: Middle East Regional Office: Alain Charles Publishing Ltd Alain Charles Middle East FZ-LLC University House Office 215, Loft 2A 11-13 Lower Grosvenor Place P.O. Box 502207 London SW1W 0EX, United Kingdom Dubai Media City, UAE Telephone: +44 (0) 20 7834 7676 Telephone: +971 4 448 9260 Fax: +44 (0) 20 7973 0076 Fax: +971 4 448 9261 Production: Donatella Moranelli, Nathanielle Kumar, Nick Salt, and Sophia White -

40

Introducing some of the latest technology for the oil and gas sector.

46

Security Synectics technology is helping to protect Shell’s huge GTL project in Qatar.

50

Reservoir Characterisation How to optimise reservoir production over the life of the field.

Flow Profiling

54

Why distributed fibre optic sensing technology offers a solution for downhole production monitoring and reservoir monitoring by overcoming the cost and technology challenges encountered with traditional point sensors.

Email: production@alaincharles.com

Arabic Section

Subscriptions: Email: circulation@alaincharles.com Chairman: Derek Fordham Printed by: Emirates Printing Press, Dubai

News Analysis

4 9

© Oil Review Middle East ISSN: 1464-9314 Serving the world of business

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Oil Review Middle East Issue Four 2013 3

News

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Libya could move oil HQ to Benghazi

NIOC attracts billions to upstream sector

LIBYA PLANS TO move the headquarters of its state oil firm to Benghazi, the city that started the uprising against Muammar Qaddafi and now wants greater influence, if a plan to restructure the corporation is approved by the national assembly. Despite about 80 per cent of Libya’s oil being located in the east, Qaddafi moved the state oil firm to the capital Tripoli and starved the eastern region of investment.

“The headquarters will be in Benghazi,” said deputy oil minister Omar Shakmak, referring to the terms of a new plan being finalised for approval by Libya’s highest political body.

Easterners have been calling for greater control over the country’s oil reserves - estimated to be the largest in Africa - since the uprising began in their region in early 2011.

At the start of the year, eastern workers and activists rejected a compromise by the government to move refining and petrochemicals to the east and even considered staging protests to threaten oil output.

Several assembly members told Reuters that easterners had since been promised the National Oil Corporation (NOC) headquarters would also move to Benghazi, but it was difficult to say when this would happen as they had not seen official paperwork yet.

“The prime minister then went to Benghazi and promised to move the NOC back to the city but no official resolution on this has been seen by the General National Congress (GNC) committee yet,” said a member of the assembly’s energy committee.

The wrangling over how to split the state oil firm has added to broader discontent in Benghazi over the prospect of further marginalisation of the east

by Tripoli and fueled calls for greater autonomy.

SENIOR IRANIAN OIL industry officials announced that they have invested a record sum of US$25bn in the upstream sector last year. The announcement was made by managing director of the National Iranian Oil Company (NIOC) Ahmad Qalebnai, adding that this amount of investment took place despite sanctions.

Qalebani said that domestic resources of the NIOC accounted for US$4.6bn of investments while the remainder was provided through finance, foreign participation, buyback and Central Bank of Iran (CBI) resources.

"In the last year two billion barrels of oil were discovered, hydrocarbon reserves rose to 156bn barrels of oil, the number of drilling rigs increased to 136, on the surface oil facilities were modernised, natural gas production rose to 622mn cubic meters per day on average and 750mn cubic meters during the days of peak consumption," the NIOC executive said.

"Early production from the Yadavaran oilfield, finding Sardare Jangle oil field in the Caspian Sea, gathering associated gases of Nargesi oilfield and launching a gas storage facility in Serajeh, near Qom with the contribution of the National Iranian Gas Company (NIGC) are among the other activities of NIOC during the last year," Qalebani added.

Gas to surpass oil - Deloitte DESPITE A GROWING focus on renewable and alternative forms of energy, oil and gas will supply about 60 per cent of global energy demand in 2040, up from 55 per cent in 2010. This and other trends, along with challenges, are explored in the recent eighth edition white paper released by the international consulting firm Deloitte. Although oil is still projected to remain the primary fuel, significant advancements in technology will cause natural gas to overtake coal as the number two fuel source, according to Deloitte’s white paper. In the Middle East, gas is forecast to overtake oil in demand after 2025, with 50 per cent of all energy demand coming from gas in 2040, according to Deloitte's white paper titled ‘Middle East Energy and Resources: Managing scarcity for the future’.

‘Most National Oil Companies (NOCs) in the Middle East already have multi-billion dollar investment plans for gas exploration and production. GCC states, particularly the UAE, Qatar and Saudi Arabia, plan to award contracts worth over US$68bn during the next five years to raise gas production,’ the report said.

"Although the share of demand for oil and gas is set to rise, it is important to note that alternative energy sources such as nuclear, wind, solar and biofuel will also take on an increasingly significant role in meeting the world’s energy needs in the future," said Kenneth McKellar, Energy and Resources leader at Deloitte in the Middle East.

With the nature of oil and gas production diversifying, strategies shifting to the unconventional, and an unprecedented rise of energy demand globally, research and development (R&D) will play a crucial role in the longevity of the industry. This is especially significant to the Middle East, where capacity building in local knowledge capital is critical to the development of the socio-economic fabric of the region. And, as the region’s NOCs look to continuously diversify across the value chain to transform into fully integrated energy companies, there is an increasing need for specialist skills. These

4 Oil Review Middle East Issue Four 2013

Gas production is on the increase across the region

skills have traditionally been brought in from abroad and through International Oil Companies (IOCs).

Nevertheless, in recent years, specialist research and training centers have been created across the region to somewhat counter this importing of skills. These centers are not only developing local talent, but are also enabling research into new innovative areas. For example, students of the UAE’s Al Hosn University recently developed a computerised fuel distribution model for Abu Dhabi National Oil Companies (Adnoc) which optimises supply and service operations while minimising environmental impact.

"Certainly NOCs also clearly see sustainability and environmental impact as key facets of the oil and gas business, and have invested heavily in these areas," said McKellar.

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News

Executives Calendar 2013 SEPTEMBER 2013 2-5

Erbil Oil & Gas

ERBIL

www.erbiloilgas.com

3-6

Offshore Europe

ABERDEEN

www.offshore-europe.co.uk

29-2 Oct

MEPEC 2013

MANAMA

www.mepec.org

OCTOBER 2013 6-8

Arab Oil & Gas

DUBAI

www.ogsonline.com

7-9

M.E. Drilling Conference & Expo

DUBAI

www.spe.org/events/medt/2013

7-10

Doha International Oil & Gas Exhibition

DOHA

www.dioge-qatar-expo.com

8-10

Kuwait Oil and Gas Show

KUWAIT

www.kogs2013.com

28-30

SPE Intelligent Energy Conference & Expo

DUBAI

www.intelligentenergy-me.com

NOVEMBER 2013 10-13

Adipec 2013

ABU DHABI

www.adipec.com

25-27

SAOGE

DHAHRAN

www.saoge.org

BASRA

www.basraoilgas.com

DECEMBER 2013 5-8

Basra International Oil & Gas Exhibition

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

Iraq set to increase production

Experts see good prospects offshore Lebanon

IRAQ IS DUE to start pumping crude from two of its largest oil fields within weeks, creating a possible obstacle to future efforts by OPEC to curb supplies in the event of a drop in prices. The Gulf state plans to start production at Majnoon imminently, followed by Gharraf in July and West Qurna-2 by year-end, lifting capacity by 400,000 barrels a day, oil minister Abdul Kareem al-Luaibi told Bloomberg in Vienna before a recent Organisation of Petroleum Exporting Countries meeting. The nation, OPEC's biggest producer after Saudi Arabia, currently pumps 3.125mn bpd, he said, without specifying output capacity.

While OPEC nations have achieved the best adherence to the Iraq holds the world’s fifth-largest oil reserves organisation's production ceiling in 18 months, the 12-member group may need to increase discipline to stem price declines, according to the Centre for Global Energy Studies.

Output from Majnoon, the country's third-biggest, will start "around midyear" and increase to 175,000 bpd by the end of 2013, Mounir Bouaziz, Royal Dutch Shell's regional vice president, said 16 May. Shell had "teething problems" mainly due to the unexpected quantities of unexploded munitions at the field, customs-related delays of imported equipment and hitches in processing entry visas, Bouaziz said.

Iraq, which holds the world's fifth-largest oil reserves, overtook Iran last year to become OPEC's second-biggest producer. The organisation no longer publishes output quotas for individual members.

OFFSHORE OIL AND gas prospects are improving day by day for Lebanon, experts and officials say, as analysis of seismic data foretells a high chance of successful drilling.

Experts on board of Al-Maram, a boat hired by the Energy Ministry for a day trip to the site of an ongoing 3-D seismic survey by Spectrum, told The Daily Star that the drilling success rate for exploratory wells would be between 40 and 50 per cent – much higher than the average in other offshore locations similar to Lebanon’s.

“Globally, the exploration success average is about one in four and here the chance of finding hydrocarbons is going to be more like one in two, because the signs from our surveys are very promising,” said Neil Hodgson, new ventures manager at Spectrum ASA. The latest survey, which covers approximately 2,200 sq-km, is being performed by sub-contractor Polarcus using their 12-streamer vessel Adira.

The completion of the new survey will mean around 90 per cent of Lebanon’s offshore Exclusive Economic Zone is covered by 3D seismic surveys, cutting short the time needed for exploration and boosting its success rate, several experts and Petroleum Administration members told The Daily Star.

Following his visit to the Adira, caretaker energy minister Gebran Bassil gave an initial estimate of 15 to 20 trillion cubic feet of potential gas findings in the surveyed area, which covers most of block 3 and parts of blocks 1, 5 and 6 of the first offshore licensing round announced on April 30 and set to be awarded in February.

Hodgson’s estimates for potential natural gas in the whole offshore zone have been upgraded, from an earlier estimate by Spectrum, to 30 to 80 TCF of gas – a wide range but nevertheless momentous.

If proven accurate after drilling, such reserves could potentially put the small Mediterranean nation among the top thirty countries in terms of natural gas reserves.

The consensus among experts is that, if a new Cabinet passes necessary decrees by September, an oil and gas company could put in place the first exploratory well in as short as 18 to 24 months. Production, however, is forecasted to commence between 2020 and 2021.

8 Oil Review Middle East Issue Four 2013

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Analysis

S03 ORME 4 2013 Analysis 01_Layout 1 17/06/2013 10:22 Page 10

Saudi Arabia is still having trouble finding guaranteed long-term conventional gas supplies. To make matters worse, its own low domestic gas feedstock prices, undercut by the shale-oil-rich US, may no longer attract petrochemical industries to the kingdom. Could a Saudi push to develop its own shale reserves be next? Independent oil analyst, Samuel Ciszuk surveys the scene.

Could shale supply

Saudi gas?

Planning a push into unconventional gas

E

VER SINCE IT reached its targeted 12.5mn bpd crude production capacity in 2008/2009, domestic demand growth has made Saudi Arabia focus more strongly on the development of its gas reserves. But gas is not as plentiful as oil. The long-term demand curve calls for very large new gas deposits to be developed, but few sizeable new gas discoveries are being made.

That said, significant gas fields are still being developed - some of them only recently discovered, raising hopes that even more conventional gas deposits may eventually be found. Last year’s ‘important’ and ‘commercial’ gas discovery in the Red Sea is still being appraised, but has already made Saudi Aramco confident enough to develop the nearby Midyan discovery from the 1980s.

Uncertain supply Nevertheless, the combination of high demand statistics and uncertain supply is encouraging a closer look at unconventional gas, particularly shale gas. Saudi Aramco believes that reserves of shale gas could be large.

10 Oil Review Middle East Issue Four 2013

The first dedicated exploration well is still some time away. However, the fact that a Saudi push into unconventional gas is being planned could signal a major shift by one of the biggest players in the global oil and gas industry.

Last year’s discovery in the Red Sea was promising, but more discoveries are needed Saudi Arabia has for years, like most of its neighbours, resisted raising domestic energy prices.

Subsidies have kept prices artificially low - along with returns to producers. However, runaway demand in the past decade and the below-zero return on any investment in power generation have stifled investment; there have been too few power plants and too little exploration for too long.

Time to catch up? Not necessarily. Supplying domestic demand is a loss-making venture. The instinct has for a long time been to keep costs to a minimum.

Urgent On the other hand, the kingdom has been able to attract some significant downstream and petrochemical investment on the basis of cheap gas feedstock over the past decade; that helped with urgently needed domestic job creation. Government efforts to provide reliable power supply and to create jobs through industrial projects are all the more urgent given the political turbulence in the region in the past few years.

For the moment, however, Saudi expansion of gas production capacity seems to be moving along well enough. The offshore 1.8 bcf/d Karan field was completed last year. The fast-tracked Hasbah and Arabiyah offshore gasfields, discovered in 2008 are making good progress. At peak demand times, the projects, through the Wasit Gas Plant, will have the capacity to deliver just over 3 bcf/d of gas to the Saudi system. Smaller projects, as well as efforts to gather associated gas more efficiently, are also reportedly moving forward.

The added production capacity should alleviate fears that not enough feedstock for the kingdom’s power sector will come onstream for the remainder of the decade.

www.oilreview.me

S03 ORME 4 2013 Analysis 01_Layout 1 17/06/2013 10:22 Page 11

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Analysis

Lead times But the unconventional gas boom elsewhere in the world could affect these plans. In the US, the cost of producing one tonne of ethylene has fallen from US$1,000 a few years ago to just around US$300 now, according to global accounting and advisory firm PWC. The equivalent production cost for Asia is US$1,717/tonne and for Saudi Arabia US$455/tonne.

Future US gas export capacity expansion will probably push prices upwards, but the lead times needed to construct export projects and the laborious political process involved in securing export permits mean that US industry may enjoy a good few years of exceptionally low gas feedstock costs. This has started to lead to a reindustrialisation, the knock-on effect of which is that industries previously moving abroad in order to stay competitive globally are looking at moving back to the US.

Saudi Arabia has for years, like most of its neighbours, resisted raising domestic energy prices In the petrochemicals sector this is already affecting the wider Gulf region in general and Saudi Arabia in particular. During the first decade of the millennium, US, European and Japanese companies seemed interested in moving production assets to Saudi Arabia, in order to benefit from the access to cheap feedstock.

Petrochemical producers were willing to face the challenges of setting up large-scale manufacturing in Saudi Arabia: these included joint venture requirements, minority stakes in the facilities, and training the often very underskilled local workforce.

Expensive The cheap feedstock, however, made up for such worries. If that were to change, so too would Saudi Arabia’s ability to compete for international petrochemical investment. A US location would allow not just cheap feedstock but a skilled workforce and proximity to market, suppliers and more developed business services.

In the light of which, Saudi plans for unconventional gas, even if it is more expensive to produce than its current conventional gas, may tell us a lot about what the kingdom sees as its conventional reserve replacement potential in the long-term. But if feedstock costs are declining elsewhere why explore shale? In fact although shale gas production will be costly at least to start with, large-scale development could get underway quickly and at a reasonable project cost. Saudi Arabia has access to one of the largest and most advanced oil and gas project management experience talent pools, a highly developed hydrocarbons industry infrastructure and access to yard and manufacturing capacity - the same factors that gave scale to US gas and oil shale production.

12 Oil Review Middle East Issue Four 2013

If feedstock costs are declining elsewhere, why explore shale?

Theoretical Also, if the shale boom does not spread to Europe and other initially promising areas, the Saudi Arabian exploration programme will be watched with greater interest - not just as an indicator of the kingdom’s shale potential, but also for what it says about the ability of a large NOC like Saudi Aramco to get hold of new technologies, transfer them to itself and internalise them in its organisation.

While it is much easier for Saudi Aramco to recruit seasoned oil and gas personnel from the US for instance, than for its Chinese or Russian peers, Aramco’s ability to execute a shale-focused exploration programme and the speed with which any possible development can be carried out will be the first real litmus test for shale technology transfers to an NOC. Still, it is necessary at this point to remember that a shale gas - or shale oil - boom in Saudi Arabia is still only theoretical. In the meantime,

the kingdom has to work with what it knows it actually has. After the wave of projects culminating with the coming onstream of Hasbah and Arabiyah, there is less optimism. Last year’s discovery in the Red Sea was promising, but more discoveries are needed.

Ironically the reining in of petrochemical investment may temporarily solve the problem of runaway domestic demand growth. It is not good news, however, for job creation - especially among the young.

Meanwhile, with the political tensions of 2011 apparently behind them, senior Saudi civil servants late last year again started talking about the possibility of raising domestic gas prices to finally rein in wasteful consumption.

Now that Saudi domestic gas feedstock prices look high compared to the US that might be a forlorn hope, and so too, as a consequence, would be hopes of a domestic supply and demand balance - for at least the short-to-medium term. ■ www.oilreview.me

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Analysis

NEW S04 ORME 4 2013 Analysis 02_Layout 1 17/06/2013 16:35 Page 14

Kuwait’s energy sector urgently needs large investments and an infusion of know-how and technology. However, years of political infighting have made progress difficult. Recent personnel changes at the top of Kuwait’s Supreme Petroleum Council (SPC) have been billed as a fresh start for investment and development. But are they? Independent oil analyst, Samuel Ciszuk investigates.

Development or

deadlock?

Kuwait needs to keep its oil production rate growing

K

UWAIT’S SUPREME PETROLEUM Council (SPC), the entity that oversees Kuwait's oil and gas sectors and sets policy, is no longer solely run by government functionaries and senior managers from state-owned Kuwait Petroleum Company’s (KPC) different subsidiaries. In the latest reshuffle, a banker and a petroleum engineer were introduced to the body. Banking expertise in particular will add some project finance and strategic M&A experience — or so it is hoped.

The change is part of a significant trend.

Despite political pressure to exclude nongovernment members from the body, supposedly to minimise the risk of conflicts of interest, government has broadened the executive group’s combined skills and experience; this, it seems, has been to the state-owned industry’s benefit.

In fact the SPC has been an island of stability in an otherwise constantly changing environment.

Kuwait has had 17 oil ministers in the past 23 years, with a consequent lack of consistent longterm strategy. Regular attempts during this period to ‘reset’ its oil and gas industry and go for growth have given way to sniping between the emirate’s main political factions, notably the royal familydominated government and an oppositionist parliament eager to carve out a larger role for itself.

Meanwhile the country’s oil industry — the source of almost all of its wealth — has suffered.

Nevertheless, there has been some success lately. During 2012 the crude production rate finally approached the three million bpd level officially claimed since the Libya crisis in 2011. This increase followed months of what many market observers saw as politically inflated production statistics, and further doubt that the state-owned industry could squeeze more production out of its largely mature reservoirs.

However, doubts over Kuwait’s ability to raise its crude production capacity go back to the beginning of the 2000s. At that time, leaked official documents were reported in the media to have put the country’s actual reserves closer to half the official number, which then stood at just under today’s 101bn barrels. Since then, Kuwait’s oil reserves, its production and the production/reserve ratio, have taken on an enhanced domestic political significance. Doubts about the country’s hydrocarbon industry in general have spread to the wider international oil and gas business, as well as financial industry circles. Peak oil theorists also pounced on ambiguities over the country’s reserves and an inability to deliver on promised production

14 Oil Review Middle East Issue Four 2013

capacity growth. The overall effect has been a trust and branding issue, both for KPC and for its subsidiaries.

Erratic project development has done little to improve matters. There had been a quick reconstruction of Kuwait’s oil and gas industry and infrastructure after the 1990-91 Iraq invasion.

However, that soon gave way to the malaise of the past 15-17 years, a malaise that has hit upstream and downstream alike. Projects have stalled, usually due to parliament’s wish to increase its own powers by sabotaging the government’s plans. And yet the effect has so far, arguably, been muted; Kuwait’s relative wealth and the oil industry’s size has meant it could carry on regardless, under technocratic management, conducting its day-today business.

But the problems have become acute in the past few years, as increased field maturity has highlighted the need for large investment in enhanced oil recovery (EOR) techniques at some of Kuwait’s largest and oldest fields, as well as development of its large heavy oil fields in the north. KPC’s national upstream subsidiary Kuwait Oil Company (KOC) for a long time lacked the know-how for this. Meanwhile the downstream industry needs an infusion of new technologies and inroads to new markets. Refineries are ageing and struggling to produce the cleaner fuels the market wants. The petrochemical industry, like upstream, also needs to find new markets and improve the quality of its output.

In recent years, Kuwait’s two largest failures have been in the downstream sector. The 615,000 bpd al-Zour refinery project was initially mooted in 2008 and intended to be onstream by 2012 but it has experienced major setbacks. The launch date is

now likely to be 2018. There have, however, been signs of possible progress. Awards had been made to South Korean companies and then rescinded in the latter parts of the past decade but recently UK’s AMEC won the first engineering contracts to be awarded for some while.

In the petrochemical sphere, KPC subsidiary Petrochemical Industries Co. (PIC) fell into a deep confidence crisis with international investors, following its withdrawal from an already agreed US$17.4bn joint venture (JV) with US giant Dow Chemicals in late 2008. The result of domestic political pressure, the withdrawal happened only days before the JV came into effect and affected all sectors of the state oil monopoly. The result was a foreign direct investment paralysis until arbitration last year called for PIC to pay Dow damages of around US$2bn.

Foreign investors feared that the relatively secure economic situation could encourage politicians to disregard the long-term technology and skill needs of oil and gas. This may still be the case. KOC has been unable to move forward with the large new development projects required to lift Kuwait’s crude production capacity to four million bpd by 2020 (a target which has been adjusted a number of times already). To do this would require a skilled foreign partner, something most parliamentarians see as far too threatening to Kuwait’s strict resource nationalist line.

Downstream, refiner Kuwait National Petroleum Co. (KNPC) faced corruption allegations as soon as a large project award was communicated. This however, may be a way for parliament to use existing powers to insert itself into the oil and gas industry, where its influence, in theory, is banned.

And yet Kuwait’s oil production capacity has

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grown. This can in all likelihood be attributed to leadership changes in the past four years within KPC and its subsidiaries and an active attempt by the Kuwaiti government and the SPC to ring-fence the technocratic leadership from negative influence by the wider political jousting.

But KOC still has the problem of not being able draw on foreign oil companies to gain new technologies. Therefore programmes to recruit a significant enough body of expertise - international and in some cases national (but with training and experience from abroad) - have focused on building the country’s EOR know-how. There are of course many knowledge issues in the wider KPC empire that need addressing. Large-scale project management capabilities, technology transfer and retention, the gas exploration and production chain, and refining and petrochemical development are only a few.

However the EOR issue has been identified as the most pressing to keep the oil production rate growing.

With improved injection technologies and facilities, as well as better reservoir management techniques and programmes, at the giant Burgan field and elsewhere, KOC was during late-2011 and 2012 finally able to start delivering growth. And that additional capacity was sorely needed; Saudi Arabia was looking to its allies in OPEC for support with its elevated production policy, to rein in crude prices.

The technical and organisational progress which underpinned the production capacity growth from around 2.6-2.7mn bpd in 2010 might have reached the end of the road for now. The more accessible reserves from the main mature oilfields have been exploited. However, as an insurance policy against mature decline this progress could be crucial in the years ahead.

Can the Kuwaiti government and the SPC keep the momentum of success going after decades of disappointments — at least for now? Ironically largescale protests on the capital’s streets may help. With various political factions busy trying to find a way to benefit from these upheavals the oil industry’s technocrats could have a slightly freer hand for a while.

We should not, however, expect an upsurge in deals with international partners; there is little legal room for that today. However, the quiet capacity buying and building strategy in the upstream sphere might lead to some progress on some of Kuwait’s oil and gas projects. But that still leaves the problem of the planned push towards a four million bpd production capacity. To make it happen requires large technology transfers and for KPC/KOC to be permitted to pursue closer international oil company partnerships. Neither are likely given the continuing political impasse.

Which is a pity. For all Kuwait’s political dysfunction, the international oil industry, would still be keen to invest in what still in many ways is an attractive spot. But attractive, or even relevant, business terms are unlikely to be offered to them any time soon. ■ Kuwait’s oil and gas sector has long-term technology requirements

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E&P

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OPEC maintains its oil output ceiling at 30 million bpd ORGANISATION OF THE Petroleum Exporting Countries (OPEC) has agreed to leave its output target of 30mn barrels bpd unchanged as oil has been held around the group’s preferred level of US$100 a barrel, industry sources announced.

The group will retain its production target for the rest of this year, said Venezuelan oil minister Rafael Ramirez, after a meeting at OPEC headquarters at Vienna recently. The group is due to meet again on 4 December 2013.

Ali bin Ibrahim Al Nuaimi, Saudi Arabia’s oil minister, had already set the stage ahead of the meeting for an easy deal, saying world oil markets were in “good shape” and balanced. That may be the case for now, he added.

But OPEC has little room to pump more oil due to the US oil boom that has sparked competition for market share in Asia.

Gulf producers, led by Saudi Arabia, are of the opinion that OPEC will still be able to pump at least 30mn bpd, provided US shale grows at a moderate pace.

“This is not the first time new sources of oil are discovered,” said the Saudi Arabian oil minister.

Despite growing supply, oil is comfortably above US$100 a barrel, but well below the US$125 that rang alarms in major consumer countries in 2012.

Iraq, meanwhile, is also fighting for more Asian market share, competing with Saudi Arabia.

But Iraq’s production and exports are not growing as swiftly as hoped due to myriad infrastructure and logistical hurdles, industry sources said.

Iraq’s federal oil minister Abdul Kareem Luaibi expects the country’s oilfields to ramp up to about 3.5mn bpd by the end of the 2013, up 400,000 bpd on current rates.

Genel finds commercial oil in Kurdistan Region of Iraq ANGLO-TURKISH OIL AND gas firm Genel Energy has confirmed a commercial oil discovery at the sidetrack of its Ber Bahr-1 exploration well on the Ber Bahr Block in the Kurdistan Region of Iraq.

Ber Bahr-1 was drilled to a total depth of 3,933 metres in May 2012. It then encountered a 300 metre oil column in the Jurassic reservoir of the Chia Zairi formation, but failed to flow hydrocarbons during testing.

UK-listed Genel Energy said that it sidetracked the well and achieved a sustainable flow rate of 2,100 stock tank barrels per day of 15 degree API oil from the Middle Jurassic-aged Sargelu formation.

According to John Hurst, head of exploration at Genel Energy, this new discovery has added to the company’s already significant Kurdistan Region of Iraq resource base.

“We plan to begin a phased development of the field in the second half of this year,” he said in a statement.

Genel operates the Ber Bahr Block with a 40 per cent stake. UK-listed Gulf Keystone holds another 40 per cent while the Kurdistan Regional Government has a 20 per cent carried interest in the production sharing contract.

Genel operates the Ber Bahr Block with a 40 per cent stake

Oman to award six onshore oil blocks for development

Apache unveils three oil and gas discoveries in Egypt

THE OMAN GOVERNMENT has announced that it is in advanced stages of negotiations with international oil companies for the awarding of six onshore oil and gas blocks for development on a production sharing basis.

Energy companies are currently carrying out geological studies Saleh Al Anboori, in 19 oil blocks director general of management of petroleum investments at the Ministry of Oil and Gas, said, “The six oil blocks, which were tendered in the previous bid round, have reached the negotiation stage. These blocks will be awarded soon. We have received bids for another seven blocks. It is in the evaluation stage at the moment.”

Al Anboori said that out of the seven blocks up for evaluation, three are offshore and four are onshore.

“The offshore blocks, namely 18, 41 and 59, are in the Sohar Basin, while the onshore blocks are spread across different parts of the country,” he added.

Eight companies are currently producing around 900,000 bpd oil per day and 93.4mn cu/m of natural gas a day in Oman. Of this, 80 per cent of the production is contributed by the state-owned Petroleum Development Oman (PDO).

Dr Al Anboori, meanwhile, added that 12 energy companies are, at present, carrying out either exploration or geological studies in 19 oil blocks in the country for production.

APACHE CORPORATION HAS reported three oil and gas discoveries in Egypt’s western desert, expanding the company’s production base in the area.

The first discovery test-flowed at a combined rate of 1,625 bpd and 529,525 cu/m of natural gas a day. Operations confirmed 2.83 cu/m of pay sands in several zones. Appraisal drilling has been planned for later this year, Apache said in a statement.

The second discovery tested at a rate of 2,041 bpd. The discovery well encountered 3.4 cu/m of hydrocarbon pay. Production is expected to begin once government approvals are received.

The third find encountered 1.6 net cubic metres of hydrocarbon pay and tested at 419,089 cu/m of natural gas and 1,522 barrels of condensate per day.

Thomas Maher, Apache Egypt region’s vice president, said, “We have been operating in the most remote areas of the country for the last 20 years.”

Egypt is a key area for Apache’s operations. During the Q4 2012, the country accounted for about 28 per cent of the company’s oil production and roughly 16 per cent of its natural gas volume.

Meanwhile, the North African country has also announced a new licensing policy for its future onshore and offshore oil and gas exploration contracts signed with foreign companies “We have developed a new system that will be implemented in the next licensing round," said Osama Kamal, Egypt’s oil minister.

“The new system will allow Egypt to increase its share of the output when production rises. The more production rises, the more our share will be.”

However, the eight oil and gas exploration projects in the Mediterranean Sea that Egypt awarded last month — for an overall minimum investment of US$1.2bn — will be excluded from the policy.

According to Kamal, the total investments in oil and gas exploration are expected to reach US$8.6bn this year.

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E&P

Barclays sees 10 per cent rise in 2013 energy E&P spending GLOBAL OIL AND gas companies, including those in Middle East, will spend a record US$678bn on exploration and production (E&P) in 2013, 10 per cent more than last year, a bank report announced.

Barclays said that it expected PetroChina Company Limited to be the world’s largest E&P spender this year, overtaking ExxonMobil Corporation for the first time since the 1980s.

The bank’s Global 2013 E&P Spending Update offered a bullish outlook on the energy industry, with oil demand Growth in the Middle East is driven mainly by continuing to outdo supply and oil companies spending higher spending forecasts for Saudi Aramco more to find deposits in more remote places.

“We do believe the industry in the early stages of a strong, sustained upcycle,” Barclays analyst James West said.

Higher spending in the Middle East, as well as solid E&P budgets in India, Australia and the rest of Asia, would offset slowing growth in Latin America, the bank report added.

Growth in the Middle East is driven mainly by higher spending forecasts for Saudi Aramco, the world’s biggest oil exporter, and increased drilling in Iraq.

Barclays forecasts a two per cent rise in E&P spending in North America this year. It had previously estimated flat year-on-year spending levels for the region.

Low natural gas prices in the United States have made drilling for gas uneconomical in many onshore fields, severely curtailing drilling activity and weighing on oilfield services like pressure pumping, which is used in hydraulic fracturing.

Higher budgets from the Chinese majors is driving the growth in the Asia Pacific region, Barclays said.

E&P companies are basing their spending budgets for the year on oil prices of US$101 for Brent, US$86.5 for West Texas Intermediate and benchmark US natural gas prices of US$3.62, Barclays found in a survey of more than 300 oil and gas companies conducted in May this year.

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Kuwait to ‘tap heavy oil’ KUWAIT HAS PLANS to start drilling for heavy oil so that the Arab state can produce up to 60,000 barrels per day (bpd) of crude by 2017, industry sources said.

The Organisation of the Petroleum Exporting Countries (OPEC) country already has a crude oil production capacity of three million bpd but wants to start drilling for the more viscous substance despite tougher extraction and processing system, Kuwait Oil Company (KOC) executive Hosnia Hashem told a local newspaper.

Hashem, deputy managing director of KOC, said, “Nearly 1,200 wells will be drilled to produce heavy oil. Each well will cost between US$525,500 and US$1.05mn to build.”

She added that heavy oil production capacity could reach 270,000 bpd by 2030 under the project, which is part of a long-term plan set out by parent group Kuwait Petroleum Corporation.

Accordin to Hashem, the global market is now seeking heavy oil.

Kuwait has three refineries and is planning a fourth under a US$105bn economic development plan announced in late 2010.

According to OPEC, Kuwait currently produced about 2.66mn bpd of oil and has proven crude reserves of 101.5bn barrels.

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Gas

Lynda Davies reports on some worrying developments for shipowners who rely on the LNG sector.

LNG project delays are bad news

for shipowners L

IQUEFIED NATURAL GAS (LNG) ship owners enjoyed a buoyant time during 2011 and 2012 amid a global surge in the demand, increasing tonne-mile demand and almost stagnant fleet growth. Global liquefaction capacity had started to ramp up in 2009, and by mid2012 the market started to firm. Then came the earthquake and tsunami in Japan in March 2011 that triggered the Fukushima nuclear plant meltdowns and led the country to shut down its nuclear plants for safety checks.

As Japan accelerated LNG buying to compensate for the closing of its nuclear plants, boosting trade and tying up vessels on longer routes and stretching the capacity of the global fleet, daily charter rates for a typical 155,000m³ vessel in the spot market soared to a record US$160,000/day last year from around US$65,000/day in early 2011 and between US$30,00040,000/day in 2010. Daily rates on three-to-five year fixtures also climbed, while the rates associated with long-term contracts moved up modestly.

Recent months have seen the gains in LNG spot charter rates lose momentum, however, amid a shortage of cargoes. The tight supply was brought about by supply issues in Egypt, Yemen, Algeria, Nigeria and Indonesia among others. As a result of the various production outages, vessels dedicated to some of those suppliers, as well as delayed new liquefaction project start-ups such as Angola LNG, were circulated on the market, adding to the competition for available cargoes, putting pressure on spot shipping rates.

Daily charter rates for a 155,000m³ ship in the spot market were down to around US$100,000/day by end-March from US$120,000 in December last year, according to data from Oslo-based shipbroker Fearnley LNG. And rates look set to decline further in the coming months and through 2014 and 2015 given the number of new LNG ships scheduled for delivery in the next two or three years and delays to new liquefaction projects.

In contrast to supply side restrictions, Asian demand for LNG remains strong “If you look at the fundamentals, there is some ground to think there will be oversupply,” said one shipping source. “The transportation capacity that is set to be added by the ships on order will be coming before new liquefaction capacity, so there will be a period where there is oversupply.”

As at the end of March this year, there were 375 LNG ships with an aggregate capacity of 54.91mn m³ (including FSRUs and trading FSRU) in service, according to Oslo-based RS Platou Economic Research. Last year, fleet utilisation was estimated to be near 98 per cent. Only two new LNG vessels (with a combined capacity of 307,600m³) were added to the world fleet during 2012 compared with 16 ships in 2011.

Nineteen new ships are set to join the fleet this year and 37 next year with a further 41 vessels scheduled for delivery in 2015 and 2016. With demolition rates expected to remain low (only four LNG ships were scrapped in 2012), the rapid growth in the fleet will not be matched by demand on account of delays to new liquefaction capacity being completed.

There were 97 LNG ships on order with an aggregate capacity of 15.29mn m³ as at the end of March, amounting to 28 per cent of the existing fleet, according to RS Platou Economic Research in its March 2013 report. At the end of 2010, the order book-to-fleet ratio was just over eight per cent.

20 Oil Review Middle East Issue Four 2013

LNG shipowners are keen to avoid the mistakes made by shipowners in the dry bulk and tanker markets

In 2011 alone, 59 orders were placed for new LNG ships compared with just five new orders in 2010. Paris-based Groupe International des Importateurs de Gaz Naturel Liquéfié (GIIGNL) said in its 2012 LNG Industry report.

Many of the orders in 2011 were placed on a speculative basis, such was the expected demand for LNG ships. LNG ship owners have traditionally preferred new-build projects to be tied to specific liquefaction projects. But reduced ship construction costs, increasing spot trade and vessel demand have encouraged speculative shipbuilding. However, with LNG ship owners keen to avoid the mistakes made by shipowners in the dry bulk and tanker markets where a glut of new vessels have hit earnings, 2012 saw the pace of new LNG vessel orders reduce. According to GIIGNL, 27 new orders were placed last year, of which 23 were for LNG carriers, and two for FSRUs, one RV and one FLNG vessel.

Recently, however, producer countries such as Nigeria and Algeria and consumers such as China as well as some shipowners indicate plans for more LNG ship orders.

But one of the biggest negative impacts on spot LNG shipping rates is the number of vessels set to come on to the market that are not committed to long-term projects and which instead will depend upon spot demand. More than one third of the 97 vessels currently on order are believed earmarked for spot charter business, according to some brokers.

Delays in the building of new liquefaction plants mean there will be less LNG to transport than previously expected, idling vessels and bringing down spot charter rates. Dedicated vessels built against specific projects could also be made available to the market if such projects are delayed coming online.

Maintenance turnarounds and unscheduled interruptions at existing liquefaction plants as well as lower-than-expected capacity additions have limited LNG supply availability in recent months. Declines in production from Algeria, and Egypt coupled with unplanned outages in Nigeria, Indonesia and Yemen among others impacted supplies. In addition, there were planned maintenance in Qatar, Australia, Norway and Trinidad. Only one of three new liquefaction projects originally scheduled to start up in 2012 came online and started shipping cargoes.

Global trade in LNG consequently is believed to have shrunk in 2012.

Preliminary data show the volume of LNG traded declined for the first time ever

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Gas

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in over 30 years by around 2.5mn tonnes to an estimated 239mn tonnes last year, according to UK-headquartered BG Group, one of the world’s largest suppliers of LNG. BG Group expects global LNG supply to continue to show low growth during 2013, earlier this year estimating year-on-year net trade growth for 2013 at only 5.4mn tonnes.

This year will see some growth in LNG exports from Australia as the Woodside Petroleum’s Pluto LNG plant near Karratha on the Burrup Peninsula produces for a full year for the first time. The Pluto plant, which was the only new LNG liquefaction project to come online last year, started up late April 2012 after several delays, loading its first cargo on the ‘Woodside Donaldson’ LNG carrier in May. The single LNG processing train has a forecast production capacity of 4.3mn tonnes/year, according to Woodside Petroleum, which owns 90 per cent of the project and is its operator. By the end of 2012, Pluto was reported to be operating at near full capacity Algeria’s state-owned oil and gas company Sonatrach began commissioning the long delayed new 4.5mn tonnes/year liquefaction train at the Skikda LNG plant in late 2012. The new train replaces three units of the GLK-1 complex destroyed in a fire in January 2004; the three units had a combined capacity of three million tonnes/year.

As at the end of 2012, the aggregate nominal capacity of world’s liquefaction plants stood at 282mn tonnes, according to GIIGNL. Supply is expected to remain tight until 2015 when new liquefaction projects in Australia as well as Canada’s first LNG export terminal are planned to come on

stream. GIIGNL president Domenico Dispenza in the organisation’s 2012 LNG Industry report noted that over the next two to three years as little as 20mn m³ of new liquefaction capacity - a mere eight per cent addition - is likely to start up.

In the second half of the decade and beyond, however, a wave of new projects, many already under construction, could help satisfy market demand growth. In addition to projects in Australia, and Indonesia, over the several years, several new LNG exporters, based in the US Gulf and on Canada’s West Coast and East Africa, are likely to start construction of liquefaction facilities.

In contrast to supply side restrictions, Asian demand for LNG remains strong. Last year, the region imported an additional 15.6mn tonnes, a growth of 10 per cent on 2011, according to BG Group. The key growth market was Japan which represented more than 50 per cent of the Asian growth, importing 87.5mn tonnes in 2012, compared to just over 70mn tonnes in 2010.

Japan restarted two of its nuclear reactors last July amid concerns over possible power shortages.

However, a rapid and sizeable restart of the country’s nuclear capacity (Japan has 50 or more nuclear reactors) is generally regarded as unlikely for the time being. In the longer term, Japan plans to phase out nuclear power in the country by 2030 as part of a major policy shift announced last year in the wake of the Fukushima disaster.

The market also saw strong import demand growth from South Korea, China and India. The three countries showed year-on-year increases in LNG imports of respectively of 3.4 per cent, 12.2 per cent and 7.7 per cent in 2012, according to GIIGNL. The growing appetite for LNG in China and India

increased the two countries’ combined global market share of LNG demand to 11.8 per cent in 2012.

Asian demand for LNG is expected to show continued growth this year, albeit at a lower rate than in 2012. This year will see the emergence of two new importers in the region; at the end of March, Singapore LNG Corporation took delivery of the commissioning cargo at its first LNG receiving terminal at Jurong Island. Malaysia will also start up its first LNG import facility in the Q2 of this year.

Israel in January started imports in January via an FSRU in the Mediterranean.

Despite the near term challenges, the long-term prospects for the LNG shipping market are expected to remain strong after 2015 as delayed projects from Australia and elsewhere start pumping LNG onto world markets and the mismatch between supply and demand starts to subside.

A number of market commentators have indicated that total LNG trade could reach around 425mn tonnes/year by 2025, although others have been more cautious in their assessments of the timing and magnitude of future supplies, citing various factors such as the scale of project costs that could lead to new developments taking longer than originally planned or some never getting off the ground.

Some observers also have pointed to the future availability of large new quantities of Australian LNG in relatively close proximity to Asian demand centres which will reduce the fleet tonne-mile requirement.

However, the more bullish LNG market watchers remain upbeat in their appraisals of how many new ships will be required to service the new future trade flows. ■

Abu Dhabi boasts gas projects worth US$25bn while offshore concessions expire in 2018, a 'well-placed oil ADNOC HAS ANNOUNCED that as much as US$73bn worth of industry source' told Gulf News. natural gas development projects were currently under tender or in engineering, procurement and construction (EPC) phases across The Abu Dhabi government is most likely to evaluate companies on GCC states Mohammad A Sahoo Al Suwaidi, director of gas their technical ability when a decision will finally taken by January directorate in Abu Dhabi National Oil Company (ADNOC), said, 2014 on foreign partnerships for onshore concessions.

“US$25bn worth of gas projects are in Abu Dhabi alone, the main The decision on partners for offshore concessions is likely to be project here being the Bab sour taken before their expiry in gas development project where 2018, said the source, adding Shell is committed to the indications are the onshore delivering gas by 2020. concessions will be offered for a “Domestic gas demand is shorter duration, and not 65 growing 15 per cent annually.” years as is the case with some Anglo-Dutch oil and gas agency existing contracts.

Shell said that it had recently Suwaidi also said the UAE’s won a 30-year deal to develop current oil production stands at ADNOC’s Bab sour gas field, a 2.77mn bpd while its natural gas project estimated to be worth output is 150,080 cu/m per day.

US$10bn. The UAE oil firm will Robin Mills, head of consulting own 60 per cent of the Bab joint at Dubai-based Manaar Energy, venture while the Anglo-Dutch said that the Middle East and company will have the North Africa (MENA) region’s remaining 40 per cent stake. gas export growth is “virtually Abu Dhabi has onshore all driven by Qatar and concessions expiring in 2014 Algeria”.

Abu Dhabi’s offshore concessions expire in 2018

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Gas

Dubai-based Well Test & MPD equipment firm focuses on next stage of growth MAGNUM TECHNOLOGY CENTER (MTC) describes itself as a 'one-stop shop for completelyengineered offshore and onshore Well Test and Managed Pressure Drilling equipment solutions'.

The equipment manufacturing and packaging firm, a wholly-owned subsidiary of the WOM group (Worldwide Oilfield Machine) has experienced rapid growth since its formation just three years ago.

According to Brian Finnigan, general manager at MTC, the company's single biggest selling point is its ability to deliver the right product faster than its rivals thanks to the massive operational experience base of its team and its multi-faceted approach to managing the manufacturing of its advanced delivery packages.

“The average delivery period of our competitors is between 16 to 20 weeks for a package item, but as we start manufacturing and customising equipment for our clients well in advance of the start of the normal ordering process we are able to deliver complete packages in less than half that time," explains Finnigan.

From its facility in Dubai's Jebel Ali Free Zone, the company also stocks equipment components and spare parts to support their clients further by being able to build non-stock equipment items www.oilreview.me

to complement their stock build packages in the same delivery timeframe. Being based in the Jebel Ali Freezone also brings to MTC the logistical advantage of being able to ship its products regionally and globally on container vessels as all of its offshore and onshore package items have been designed to be shipped as a container or in a container.

“Our rapid delivery to market concept improves massively the capability of our clients to meet the ever reducing deadlines required to remain competitive in the current Oil and Gas operating and service sector,” Finnigan further explains.

MTC’s key markets stretch across the wider Middle East, East Africa, Asia, Europe and as far as South America, and it has also been eyeing up the growing West African E&P market, while some of its products have made it as far as South Africa. It has also doubled its year-onyear revenue in the last three years.

"One of the biggest advantages we have is that we have grown organically year on year helped hugely by being a part of the WOM Group of Companies," remarks Finnigan. "We want to continue to improve the product deliverability combined with increasing our market share to allow us to hit the next level in our development."

The firm is currently doubling the size of its 12,000 sq m Jebel Ali facility with a carbon copy of its current facility being built on the adjacent plot.

"We are also striving to bring forward new products that will complement MTC's existing product range," says Finnigan. "We are going into a new phase of expansion that should be evident within the next six to nine months."

"We hope to bring more global business to our table as being based ourselves in the free zone allows us to centralise our equipment stock and ship it rapidly on a global scale," he adds.

An innovative approach to design, along with the freedom of being a Dubai Free Zone company and the trust of its backer, WOM has led MTC to enter into the next exciting stage of its development from its logistically-favourable base in Jebel Ali.

CA self-contained trailer mounted well test package sits outside the companies Jebal Ali facility

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Gas

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Abu Dhabi to host oil and gas summit

Excelerate to construct LNG terminal

ENERGY MINISTRIES AND Oil gas companies plan to discuss exploration and production (E&P) activities in sub-Saharan Africa and the Middle East region during the forthcoming ‘Africa and Middle East Oil & Gas Summit’.

The two-day event which has been organised by UK-based business research firm, Oliver Kinross, will be held in Abu Dhabi from September 30 to October 1.

The event will welcome high-level representatives from Africa and the Middle East’s oil and gas industries.

Among those attending the summit will be Breitling Oil & Gas CEO Chris Faulkner, who has recently highlighted the importance of developing oil and gas industries.

“There has never been a greater time to be in the energy business,” Faulkner said.

Key players in the oil and gas sectors will enable cooperation between the Middle East and Africa.

The programme for the two-day event includes a conference, panel discussions, a 40-booth interactive exhibition, a networking event and sessions for delegates on East Africa, southern Africa and West Africa as well as hearing keynote speakers address hotly debated issues.

Speakers at the summit will include the director of the department of petroleum resources, Nigeria, Osten Olorunsola.

EXCELERATE ENERGY HAS been awarded a contract to build a liquefied natural gas (LNG) import terminal in the UAE, it revealed.

Emirates LNG, a joint venture between Abu Dhabi’s Mubadala Petroleum and International Petroleum Investment Company (IPIC) selected Excelerate for the deal over Norway’s Golar LNG, the company stated.

The facility at Fujairah, which is situated on the East coast of the UAE outside the Strait of Hormuz, is projected to have an annual import capacity of 9mn tonnes of LNG, Emirates LNG said.

The UAE has transported LNG from fields in the Gulf since the late 1970s but its own rapidly rising demand and slow production growth has made the OPEC member a net importer of gas over the last few years.

Rather than constructing a full-scale import terminal, over a long time period, Emirates LNG assessed floating storage and regasification units issued

by Excelerate and Golar.

Dubai imports LNG to ports in the Gulf and the UAE recieves a modest volume of Qatari gas through pipeline, which can feed power and desalination plants at Fujairah.

The Emirates LNG import terminal will be constructed next to a power and desalination plant at the booming industrial and oil storage centre.

Building an LNG import terminal outside the Strait of Hormuz is expected to lower the risk of the UAE's supplies being affected by issues in the oil and gas shipping lane.

Aramco begins construction for Midyan gas field

KOGAS hosts Gastech 2014 conference

GLOBAL PETROLEUM AND chemicals company, Saudi Arabian Oil Co, or Saudi Aramco, said construction has commenced for its US$300mn Midyan gas field in the northwest of Saudi Arabia.

The oil and gas company, which is involved in exploration, production, refining, distribution, shipping and marketing activities, plans to increase gas output to meet rising domestic demand.

"The project will include building two pipelines of 98 km length to deliver sales gas and hydrocarbon liquids to a power plant near (the western city of) Duba," al-Helal said in a statement.

A new contract for the construction of the gas plant with the Saudi unit of India’s Larsen & Toubro Ltd marked the launch of the project, Aramco stated.

The Midyan gas plant, situated around 195km west of Tabuk and 135km north of Duba, is set to be up and running by 2016, it said.

Starting operations in 1992, the gas plant is expected to produce 75mn standard cu ft a day of non-associated gas and 4,500 bpd of condensate.

Aramco also plans to construct two pipelines to transport sales gas and stabilised hydrocarbon liquids to a power plant near Duba to produce electricity.

Saudi Arabia plans to increase gas production to meet domestic energy demand and free up crude oil for export. The country, however, has not yet discovered non-associated natural 8gas in enough quantities to substitute oil as the fuel for its proposed electricity plants.

G A S T E C H KOGAS will welcome visitors at Gastech 2014 from across 2014, a natural the upstream, midstream and downstream sectors gas conference is currently requesting abstracts for commercial and technical presentations.

The event, which is set to take place next year, will make its debut in South Korea starting from 24-27 March from at KINTEX 1, backed by its host sponsor KOGAS and is set to bring industry professionals together from across the upstream, midstream and downstream sectors.

Gastech aims to bring together key producers, consumers, distributors, engineering firms, shippers, it said.

“It’s a dynamic, flourishing time for the natural gas and LNG industry, particularly in Asia," said Gavin Sutcliffe, head of content for Gastech.

24 Oil Review Middle East Issue Four 2013

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Gas

S07 ORME 4 2013 Gas 02_Layout 1 17/06/2013 11:32 Page 26

Hiring in regional oil and gas sector up 18 per cent

Saudi Arabia gas sector to sustain self-sufficiency

COMPANIES IN THE Middle East are seeking to grow their manpower, with the number of staff roles provided by recruiters in the Middle East increasing by 18 per cent, a signicant rise from a year ago.

“Competition between recruiters has never been greater, with organisations offering attractive packages. We have seen inflation in salaries as oil and gas majors compete for experienced individuals with a skill set that is adaptable to new technologies,” said Mark Guest, managing director of OilCareers.com.

Companies in the oil and gas sectors such as the Middle East, Europe, Australia and Canada have centred their efforts around unconventional energy, such as natural gas, gas condensates, crude oil, tight gas, coal bed methane, oil sands and heavy oil reserves.

“Natural resources require greater levels of technology and investment from oil and gas majors accelerating the need for skills to extract these assets,” said Guest.

SAUDI ARABIA WILL stay self-sufficient in natural gas, with production increasing from an estimated 116.2bn bcm in 2013 to 152bcm by 2022, according to estimates published by Business Monitor International.

With industry estimates putting the country's retrievable shale gas resources at an estimated 18.1tcm in April 2012 and demand coming from domestic consumption, Aramco announced a revised timetable for shale gas development.

Besides new offshore drilling projects, Saudi Arabia will see record rig counts as it aims to discover unconventional gas before 2020.

Moreover, for 2013, the report expects crude oil production to rise to an average for the year of 11.6mn bpd, with natural gas liquids (NGL) and processing gains bringing total liquids.

Saudi Arabia has accelerated various projects as it seeks to increase use of gas as feedstock for both power and the petrochemicals industry.

A strong growth in gas production is expected, with a number of new projects in the pipeline brought forward in recognition of the growing domestic consumption.

The Organization of Petroleum Exporting Countries (OPEC) will limit crude shipments as demand from Asian refiners drops during seasonal maintenance, tanker tracker Oil Movements said.

Producing around 40 per cent of the world's oil, OPEC, will ship 23.7mn bpd in the four weeks to June 22, dropping one per cent from 23.93mn in the previous period to May 25. Both Angola and Ecuador are not included in the estimates.

According to Oil Movements, “Middle Eastern shipments will slip by 1.1 per cent to 17.4mn barrels a day, compared with 17.6 mn in the month to 25 May.”

The Middle East's gas sector has recently faced stiff competition between recruiters seeking to fill various roles

26 Oil Review Middle East Issue Four 2013

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Petrochemicals

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The Middle East’s petrochemical companies must be flexible, sustainable and prepare to enter new, dynamic markets as the region is tipped to dominate the global industry by 2020, said industry experts at the Fifth Annual GPCA Supply Chain conference, held recently in Dubai.

Region to dominate petchems

by 2020 O

RGANISED BY THE Gulf Petrochemical and Chemical Association (GPCA), the fifth Supply Chain Conference was opened by Saleh Al-Shabnan, vice chairman of GPCA Supply Chain Committee and vice president of Global Supply Chain Centre of Excellence, SABIC. Al-Shabnan said that sustainability will be one key area to focus on going forward as the industry continues to develop.

“Supply chain management in the Gulf is evolving and now is the time to look at important opportunities and close any gaps.

One [such issue] is the sustainability of the supply chain in the Gulf. The perception is that the region is blessed with energy resources and therefore is not cautious about this. The supply chain industry here is as cautious as other regions, if not more so,” said Al-Shabnan.

Initiatives To address the issue, SABIC is rolling out five initiatives that will improve fuel efficiency, reduce CO² emissions and energy consumption.

Al-Shabnan - sustainability the key

28 Oil Review Middle East Issue Four 2013

These five initiatives are: reduce transportation time between plants and consumers; replace 200,000 trucks with 2,700 trains to run on Saudi Arabia’s railway network with the support of SAR; implementing a fuel savings programme which will also reduce CO²; use larger and more sophisticated ships to transport products more efficiently to distant markets, such as the US and Asia; and to use pipelines more for the transport of liquid products.

By implementing these initiatives, SABIC aims to reduce its energy consumption by 0.7 MMBOE (million barrels of oil equivalent) by 2016.

Reducing energy consumption will be crucial as the industry continues to develop at

SABIC is rolling out five initiatives that will improve fuel efficiency

a rapid rate. In his keynote address, Puneet Madan, head of supply chain management (Polymers), Reliance Industries, India, said that the Middle East will have 386 production plants by 2015, producing 172 mMT of finished petrochemical products in that time.

The Middle East, therefore, will continue to dominate the sector, despite facing challenges such as economic and political volatility, piracy, maritime restraints and environmental restraints.

In fact, the region comprises part of the new hub for the global chemicals industry China, India, Middle East and Africa (CHIMEA) region, said Michael McCool, Partner and General Manager, A.T Kearney, Hong Kong.

“Over 25 years, three of the top 10 chemical firms will be in that region. We need to be eastwards looking, not westward looking, and looking to produce in China and Asia because of this shift. By 2020, the Middle East will become the central hub for the global petrochemical supply,” McCool said.

Sustainable To ensure the Middle East stays ahead of its competitors, the GCC petrochemical industry will need to develop in a more sustainable way and be more flexible to better respond to the changing market dynamics.

Africa is one region which offers many new opportunities for firms in the Middle East, with two of the top three fastest growing economies on the African continent- Guinea and Ghana, McCool added.

“Africa should be seen as a natural backyard for you [petrochemicals industry in the Middle East] and where the Middle East should succeed better than its competitors,” McCool said.

The first day of the conference was attended by 328 delegates and industry experts, with panel discussions held on the topics of Global Supply Chain Trends, Changing Supply Patterns in the Arabian Gulf and Creating Value Through Integrated Logistics.

The Gulf Petrochemicals and Chemicals Association (GPCA) is the voice of the industry in the region. Established as a non-profit organisation in March 2006, it is the first trade association in the Gulf and the largest and most respected industry body representing the downstream sector in the Middle East. ■ www.oilreview.me

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Petrochemicals

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Skilled workforce will help companies thrive THE REGION’S PETROCHEMICAL companies will thrive if they focus on developing their talent base, according to the latest research by Gulf Petrochemicals and Chemicals Association (GPCA) and Accenture. The report, titled ‘Finding, Developing and Retaining Supply Chain Talent in the Arabian Gulf’, was released during the Fifth Annual GPCA Supply Chain conference in Dubai.

Marking the first collaboration between GPCA and Accenture, the report gives recommendations to petrochemicals companies in the Gulf region on leveraging human resources to drive growth in this sector.

According to joint research by GPCA Accenture, the GCC region produces less than one- half of the

supply chain professionals it needs. This comes despite the fact that employment in the GCC petrochemicals sector has a year on year growth of 15 per cent, as per GPCA findings.

The sector also has growth potential - the petrochemicals employee base accounted for six per cent of the total GCC manufacturing workforce in 2011, up from five per cent in 2010.

“The regional petrochemical industry is typically involved in high capital projects, involving a very skilled workforce. A more integrated approach to supply chain talent will help lead to the development of a regional knowledge economy,” said Dr Abdulwahab AlSadoun, secretary general, Gulf Petrochemicals

and Chemicals Association (GPCA).

Despite the petrochemical industry retaining an estimated 44 per cent of national employees, a shortage of local supply chain skills has been identified in the report. Since regional governments actively discourage the employment of expatriates, it is now vital for local petrochemical companies to find, develop and retain local supply chain talent.

“The growing scale of the GCC petrochemicals market demands a more sophisticated workforce,” said Dr Sadoun.

“The GPCA-Accenture report explores the tools and best practices that supply chain managers need to implement in order to develop future talent in the petrochemicals workforce.”

Qapco’s ‘green’ initiative QATAR PETROCHEMICAL COMPANY (Qapco) is set to complete two major projects in as many years as part of its nearly QR600mn (US$165mn) initiative to minimise emissions and safeguard the environment.

With these projects, Qapco aims a significant reduction in nitrogen oxide and carbon dioxide emissions to the air.

Speaking to Gulf Times, Qapco vice-chairman and CEO Dr Mohamed Yousef al-Mulla said the company was currently replacing its power generation facility and old furnaces that were set up in the Mesaieed plant in the 1970s and 90s.

“With new technology coming in, we will be able to improve our performance with relation to environment protection. Already we are well within the limits set by the www.qapco.com.qa Ministry of Environment,” al-Mulla said.

He said the projects would be executed during 2014 (when a general shutdown has been planned) and in 2015.

Al-Mulla said Qapco was also investing heavily on “risk mitigation” relating

30 Oil Review Middle East Issue Four 2013

to the IT technology.

“Risks today are not just in the area of environment or general safety.

Risks are posed by hackers and combating them is top on our priority.

We are executing a project worth QR120mn (32.9mn) in this regard,” the Qapco CEO said.

The company is also spending considerable amount on a seawater discharge project.

Al-Mulla highlighted Qapco’s commitment to improve energy efficiency.

“We have been in operation for more than 40 years now. We continuously invest in modernising and upgrading our facilities, adopting the latest and most sophisticated technologies and monitoring systems to optimise our energy consumption, while reducing our environmental footprint. Our latest facility for instance, the LDPE 3 plant uses the latest technology to improve production efficiency while increasing the overall production capacity,” he said.

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Petrochemicals

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UAE to get first FCC unit in Middle East THE UNITED ARAB Emirates is set to get the first fluid catalytic cracking (FCC) unit in the Middle East by 2015.

The plant will be located 70km from Abu Dhabi in Kizad Industrial Zone and will be built by US-based Grace Catalyst The plant will be located in Kizad Industrial Zone, 70km Technologies. from Abu Dhabi Construction is set to begin in Q3 2013 and operations are likely to start in 2015, Grace Catalyst Technologies said.

A logistics hub will be completed in the Q1 of 2014.

The FCC process reportedly speeds up production of petrol and liquefied gas from heavy oil.

According to Shwan Abrams, president of Grace Catalyst Technologies, US$200mn will be invested in the construction of the plant.

Abrams said, “This is the main investment we have made outside North America. The installation should generate some 200 jobs.”

FCC is gaining ground in the Middle East due to the presence of heavy oil.

Chiyoda and CTCI sign US$1.5bn Qatar’s Laffan Refinery 2 deal A JOINT VENTURE of Japan-based Chiyoda Corporation and Taiwanese CTCI Corporation has been awarded a contract for the engineering, procurement, supply, construction and commissioning (EPSCC) of the US$1.5bn Ras Laffan Refinery 2 (LR 2) project in Qatar.

The deal was signed by Qatar minister of energy and industry Mohammed bin Saleh Al Sada, Chiyoda Corporation chairman Takashi Kubota, and John T Yu, chairman of CTCI. LR2 will have a processing capacity of 146,000 bpd, similar to the existing Ras Laffan Refinery (LR1), and will be operated by Qatargas.

Adjacent to LR1, LR2 is expected to have a daily production capacity of 60,000 barrels of naphtha, 53,000 barrels of jet fuel, 24,000 barrels of gas oil and 9,000 barrels of liquefied petroleum gas (LPG).

Al Sada said, “The agreement is in line to ensure the optimal utilisation of our country’s natural resources while contributing effectively to securing energy supplies for the local and international markets.”

Khalid bin Khalifa Al Thani, Qatargas CEO, commented, “LR2, while improving product distribution domestically, will also help meet the increasing demand of international customers for cleaner fuel products.

Qatargas will manage the EPSCC activities and eventually operate the facilities on behalf of the shareholders, utilising the synergies available in Laffan Refinery 1, which hasbeen in operation since 2009.”

Salman Ashkanani, Refinery Ventures’ CEO, added, “The new expansion project will double the existing capacity of the Laffan Refinery to a total of 292,000 bpd.”

Maintenance centre for Abu Dhabi T.D. Williamson (TDW), a worldwide provider of equipment and services for operators of pressurised piping systems, announced that it has opened a new maintenance center in Abu Dhabi. To mark the opening of the facility, approximately 65 representatives from customer organisations and agents of TDW from the Gulf Cooperation Council (GCC) region recently attended a Grand Opening event. The event included a ribbon-cutting ceremony and facility tour. Guests had the opportunity to view a wide range of TDW systems, including hot tap and STOPPLE® plugging machines, and gas magnetic flux leakage (GMFL) and high resolution deformation (DEF) inline inspection (ILI) tools. Guests were also invited to learn more about data analysis techniques and pipeline repair solutions.

The addition of the new 7,500 square foot facility represents the first phase of TDW plans to expand in the region. The facility complements the existing 7,500 square foot Hot Tap and STOPPLE Plugging Service Center by adding a stand-alone maintenance capability aimed primarily at the ILI regional market.

Pictured (left to right) at the ribbon-cutting ceremony to open the new TDW Maintenance Center in Abu Dhabi are Danny Haykal, director - Middle East & Africa for TDW, Marwan Faraj Bin Hamoodah - board member of the Bin Hamoodah Company, Matthew Wicks, operations manager - Pipeline Integrity Operations for TDW, and Nick Dring, operations manager - United Arab Emirates for TDW.

32 Oil Review Middle East Issue Four 2013

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Saudi Arabia

The world’s biggest oil producer Saudi Aramco is now exploring a whole new business area; power generation.

Aramco explores new

power sector role T

HE STATE-OWNED SAUDI company is keen to roll-out extra generating capacity not just to ease the nation’s energy crunch, but to guarantee electricity supply to its own huge network of oil and gas facilities and infrastructure up and down the country.

With spare upstream crude oil production capacity available for the world market if required, it has allowed the company to take on new projects across the energy spectrum, including more downstream work in refining and petrochemicals, as well as power generation.

And it’s a role that Aramco is being urged to take with officials increasingly focused on domestic issues, including raising the availability of power supply, utilities and other services for a fast growing economy and a youthful, aspiring population.

Getting to grips with the nation’s domestic energy challenges will also take some of the pressure off state power utility Saudi Electricity Corporation (SEC), which is leading a massive roll-out of new generating infrastructure.

A growing population means growing consumption, which means the domestic demand for energy could double by 2030, according to some projections.

Aramco appointed KBR to lead the frontend engineering and design (FEED) work on the new Integrated Gasification Combined Cycle (IGCC) project.

The US-based contractor is also working on the associated Jizan refinery project.

It’s a huge, state-of-the-art undertaking for the oil company and its team.

Once complete, it will be the largest gasifier-based power facility built in the world.

The IGCC complex will convert vacuum residue to electricity and utilities for industries around the Jazan economic city and the surrounding region.

Aramco's CEO Khalid al-Falih said the refinery and associated infrastructure will be the nucleus for the Jizan economic city and play a major role in the development of one of the kingdom’s poorer regions.

Growing portfolio The Jizan power project marks a big step up for Aramco in the electricity generation sector but it is certainly not a one off.

In fact, the group’s involvement in the power sector dates back more than a decade with the formation of Marafiq, the power and water utility company for Jubail and Yanbu, back in 2000.

This Aramco venture - which groups it with the Royal Commission for Jubail and Yanbu, Saudi Basic Industries Corp. (SABIC) and the Public Investment Fund (PIF) - produces and distributes electricity and potable water to the surrounding area as well as as supplying seawater to industry and treating industrial wastewater.

Fast-forward to 2013, and a number of other new projects are now rapidly advancing.

At the end of 2012, contractors filed bids for three new Aramco co-generation power and steam plants at Abqaiq, Hawiyah and Ras Tanura.

It’s a different and much smaller proposition than Jizan, with a total capacity from all three installations of around 700 MW, but these new projects will collectively propel Aramco into a key - and growing - power

In addition, there are vast open spaces of desert, where large solar farms can be established on relatively cheap real estate Jizan project Right now, Aramco is moving ahead on a large generation project, worth around US$2bn, that will help supply the 400,000barrel-per-day (bpd) Jizan refinery, in the southwest of the kingdom.

The 2,400MW power project is to be built to provide 500MW of electricity to the US$7bn heavy oil refinery which is now under construction at a nearby site.

The surplus capacity will be available for other downstream and industrial projects to be built at the new Jizan economic city.

34 Oil Review Middle East Issue Four 2013

The Kingdom is facing significant energy challenges

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S09 ORME 4 2013 Qatar_Layout 1 17/06/2013 11:36 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, Ethiopia 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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Saudi Arabia

S09 ORME 4 2013 Qatar_Layout 1 17/06/2013 11:36 Page 36

means the plant can continue operating under its own power generation despite interruptions in electricity supply from the utility company.

The concept involves isolating the plant and its generators from the local power grid.

Previously, any disturbance from the grid could cause a blackout, disrupting operations and causing revenue loss and making flaring necessary.

The new system means plant generators can now withstand any disturbance to the power supply.

At present, the oil company has an estimated 2,000MW of installed generating power capacity internally The potential of the solar sector alone is simply immense

sector player in the Saudi market.

At present, the oil company has an estimated 2,000MW of installed generating power capacity internally, but it sees this rising to over 5,000MW by 2015 as new projects come onstream.

More is likely to follow with Aramco broadening its involvement in all areas of the energy chain.

Performance and efficiency and Technology (KAUST) on the kingdom’s western coast, it has put together another facility with a capacity of two megawatts.

These pilot projects puts Aramco in a strong position to exploit other emerging opportunities in the renewable energy segment and understand better the key technologies involved.

Innovation Renewables interest And naturally that will include some participation in the kingdom’s high potential but lightly developed solar and renewables sector.

Saudi Aramco president and chief executive Khalid A. al-Falih recently inaugurated a 3.5 MW solar energy field in Riyadh at the King Abdullah Petroleum Studies and Research Centre (KAPSARC).

The solar energy field was built over an area of 55,000 sqm, making it the biggest ground-mounted solar installation linked to the electricity grid in the country.

The facility will supply about 5,800MW hours of electrical energy annually, and offset carbon (CO2) emissions by about 4,900 tonnes every year.

The flagship installation, which underscores Saudi Arabia’s immense solar energy potential, uses 12,684 fixed-angle Polycrystalline PV panels provided by Suntech with 14.4 per cent efficiency, and maximum power of 280 watts at standard test conditions.

The DC power generated by the panels is collected and inverted to AC power through four inverters. Ahead of this project, Aramco also built the world’s largest solar energy generation unit on a car park roof with a capacity of 10MW. And in King Abdullah University of Science

36 Oil Review Middle East Issue Four 2013

The landmark Riyadh solar field also highlights how Aramco’s power business is keen on innovation and breaking new ground, a role it has taken on admirably for years in the oil and gas sector.

The potential in the solar sector alone is simply immense.

The kingdom experiences roughly 3,000 hours of sunshine each year, emitting about 7,000 watts of energy per square metre, among the highest in the world, showing how great the potential for further renewables development.

In addition, there are vast open spaces of desert, where large solar farms can be established on relatively cheap real estate.

And the kingdom is also blessed with deposits of quartz which can be used in the manufacture of polysilicon and photovoltaic cells.

Outside the renewables segment, the company is also exploring innovative new power solutions to safeguard the integrity of its huge oil and gas infrastructure, the lifeblood of the Saudi economy.

In one example, Aramco worked with Mitsubishi Heavy Industries of Japan and SEC on a two-year project to develop a groundbreaking power generation concept at the Berri gas plant.

The Beri ‘islanding’ system, as it is known,

And it seems Aramco is intent on doing things the right way too, utilising state-of-theart technology to reach for the best performance.

At a recent industry conference, Ziyad alShiha, executive director of power systems at Aramco, said this meant delivering the very highest levels of performance from all of its generating plant.

“We will try to generate the additional power in the most efficient way, reaching efficiency levels of 75 per cent; this is compared with levels of 39 per cent in OECD countries,” he said.

Saudi demand for electricity has increased by about seven to eight per cent annually for the past five years, which means being energy efficient in all areas of the industry, is a national priority.

It will mark a break from the past, however, with even Saudi’s oil minister Ali Naimi flagging up the country’s dismal energy efficiency levels up till now.

And even bolstering Aramco’s own power supply capacity could ease the country’s alarming dependence on its own oil for generation.

According to some forecasts, the kingdom may need to burn as much as three million bpd by 2020 to generate power if it doesn’t improve efficiency; the figure may already reach as high as one million bpd, according to some estimates.

The growth in local power and water demand is huge, and the investments required are huge.

These are big challenges for all concerned, but now Saudi Arabia’s state oil giant is stepping up to the plate to ease at least some of the burden.

It’s a welcome new participant in such a challenging environment. ■ www.oilreview.me

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Qatar

Qatar Shell has unveiled new supply chain business opportunities for local companies following the agreement it signed with Qatar Development Bank (QDB) earlier this year to provide local companies and manufacturers access to new business opportunities.

Opportunities for

local SMEs Local SMEs could soon be providing equipment and services at the Pearl GTL plant in Qatar

T

HE MOVE BY Qatar Shell is part of its drive to increase the number of Small to Medium Enterprises (SMEs) acting as contracted suppliers for its operations in Qatar, the company said.

The step will pave the way for qualified local companies to become the supplier of choice for Qatar Shell as well as the Pearl GTL plant, the world’s largest Gas to Liquids plant.

“Qatar Shell’s aim is to support the Qatar National Vision 2030 and one area of focus is in the development of local content and SMEs, not just through sponsorships but by actively providing business opportunities and developing companies to achieve world class standards to compete with global companies,” Wael Sawan, managing director and chairman of Qatar Shell Companies, said.

“These new supply chain business opportunities are a great example of this objective and we are proud to bring this to the market with QDB’s partnership,” he said at the unveiling ceremony in the Qatari capital Doha.

Mansour Bin Ebrahim Al Mahmoud, QDB chief executive officer, said that “developing a thriving private sector is an important priority and one that is integral to the mission of QDB.” “Qatar Shell shares QDB’s aspiration to develop a robust private sector and they have committed to present a number of business opportunities for local SMEs. “As a start, four specific and immediate business opportunities were presented in the workshop which will allow us to move to the next phase of this journey of collaboration between QDB and Shell,” he said in remarks to Gulf News.

The four local business opportunities were manufacturing of Personal Protective Equipment, heat exchanger re-tubing for the Pearl GTL plant, manufacturing stud bolts for the Pearl GTL plant, and translation services.

38 Oil Review Middle East Issue Four 2013

Meanwhile, Qatar Petroleum and Qatar Petrochemical Company have signed technology licence contracts for the multi-billion dollar Al Sejeel petrochemical complex with Univation Technologies for the polyethylene technology and The Dow Chemical Company for polypropylene technology.

The contracts were signed at a ceremony attended by HE the minister of energy and Industry, Dr Mohamed bin Saleh al-Sada.

QP and Qapco had signed the Heads of Agreement (HoA) to jointly develop the megapetrochemical complex in Ras Laffan in February 2012.

QP and Qapco hold 80 per cent and 20 per cent equity interest respectively in the project.

The Al Sejeel Petrochemical Project is scheduled for completion in 2018 and will feature a world-scale mixed-feed steam cracker, with the original mixed feedstock of ethane, butane, and naphtha, thus allowing extra flexibility and diversity in terms of products.

QP and Qapco said the selection of the licensors was a highly strategic landmark and highlights the evolution of the project.

With the signing of the technology agreements, the Al Sejeel plants will be designed to produce 2.2mn tonnes per year (tpy) of polymers, including polyethylene and polypropylene resins.

Qatar Petroleum (QP) has signed two contracts for the offshore drilling rigs, Al Doha and Al Zubarah, of Gulf Drilling International Ltd (GDI) for use in QP’s offshore fields.

The contracts were signed by H E Dr Mohammed bin Saleh Al Sada, minister of energy and Industry, and QP chairman and managing director, and Ibrahim J Al Othman, chief executive officer of GDI. Each agreement is for a five-year extension of both offshore rigs’ contracts, which will end in 2018. The combined value of the two contracts totals QR1.7bn (US$466mn).

Dr Al Sada commented: “Qatar Petroleum places high priority on the development of national oil service companies, and is pleased to give its full support to GDI.” He praised GDI’s rapid development and said QP was appreciative of the high quality of service that it provides.

Ibrahim J Al Othman, chief executive officer of GDI, said: “GDI is fully aware of the value resulting from the support it receives from Qatar Petroleum. Working with QP has granted us the chance to develop our skills, technologies and the required competencies to be a world-class drilling service provider. I would like to take this opportunity to express my sincere gratitude and deep appreciation for the support and guidance of H E Dr Mohammad bin Saleh Al Sada and thank QP’s operations directorate for their continued support to GDI.”

The step will pave the way for qualified local companies to become the supplier of choice for Qatar Shell GDI is the first onshore and offshore oil and gas drilling company in Qatar and is a subsidiary of Gulf International Services (GIS), which is listed on the Qatar Exchange. GIS holds 70 per cent of the shares of GDI, along with 100 per cent of the shares of Gulf Helicopters, Amwaj Catering Services and Al Koot Insurance Company.

GDI’s fleet currently consists of six offshore rigs, six onshore rigs, and one offshore accommodation jack-up and one lift boat operating in Qatar. GDI’s major clients are Qatar Petroleum, Occidental Petroleum of Qatar, RasGas, Qatar Shell, Dolphin Energy and Maersk Oil Qatar. ■

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S10 ORME 4 2013 Innovations_Layout 1 17/06/2013 11:43 Page 40

Web selection - Innovations from www.oilreview.me A selection of recent products and service developments for the oil and gas sector.

Full information can be found on www oilreview.me

Alderley bags KOC Telemetry Project ALDERLEY FZE WILL provide gas and liquid metering skids for the Kuwait Oil Company’s (KOC) Telemetry Project in Kuwait. The scope of supply will include gas ultrasonic metering skids, gas coriolis metering skid, liquid ultrasonic metering skids and liquid coriolis metering skids.

Finning Power Systems intoduces offshore drilling module FINNING POWER SYSTEMS (Finning) has launched a fuel-efficient Cat C175-16 offshore drilling module as part of its comprehensive portfolio of power solutions for oil and gas applications.

Full details can be found at www.oilreview.me

E+ E Elektronik launches new flowmeter E+E ELEKTRONIK’S NEW thermal flowmeter has the capacity to record the mass flow or corrected volume flow of compressed gases in a supply network with precision, regardless of pressure or temperature.

The new flowmeters can enable precise evaluation

Full details can be found at www.oilreview.me

FPIG acquires Specialty Plastics FUTURE PIPE INDUSTRIES Group (FPIG) has acquired 100 per cent stake in fibreglass reinforced pipe business, Specialty Plastics, Inc from ITT Exelis. The takeover is a strategic addition to FPIG’s composite pipe business and adds a new offering to its extensive product range.

Full details can be found at www.oilreview.me

New softwares for offshore industries STAR INFORMATION SYSTEMS and StormGeo will work together to develop a range of innovative software solutions for offshore and shipping industries.

Full details can be found at www.oilreview.me

Trelleborg’s new sealing materials Trelleborg Sealing Solutions has launched 20 seal materials specially designed to meet differing operating conditions in oilfields in terms of media resistance, life expectation, friction and wear requirements.

Full details can be found at www.oilreview.me

The seal materials meet API and ISO specifications

40 Oil Review Middle East Issue Four 2013

C175-16 provides up to 20 per cent more installed power

Full details can be found at www.oilreview.me

Egypt gets GE’s vessel-control simulator GE Energy Management’s Power Conversion business and the Arab Academy of Science, Technology & Marine Transport has opened a jointly developed, dynamic positioning vessel-control simulator in northern Egypt to address the demand for trained workers.

Full details can be found at www.oilreview.me

EQUATE selects Gulf Cryo for CO2 recovery project EQUATE PETROCHEMICAL COMPANY has signed an agreement with Gulf Cryo for Kuwait’s Second CO2 Recovery Project. Gulf Cryo will obtain CO2 from EQUATE’s plants to be converted and used for industrial purposes.

EQUATE and Gulf Cryo team members at the agreement signing ceremony

Full details can be found at www.oilreview.me

Yokogawa releases CCD colour camera YOKOGAWA ELECTRIC HAS launched the first model in the FIELDEYE II series, which consists CCD cameras for monitoring plant facilities. The model is non-explosionproof and has pan-tilt zoom.

Yokogawa plans to release an explosionproof model by 2013 end.

Full details can be found Thie FIELDEYE II all-weather CCD camera is compact at www.oilreview.me in size and features best-in-class performance www.oilreview.me

S10 ORME 4 2013 Innovations_Layout 1 20/06/2013 10:14 Page 41

Innovations

S10 ORME 4 2013 Innovations_Layout 1 17/06/2013 11:43 Page 42

Rotork opens purpose-built factory in Dubai

Rockwell tools to simplify machinery safety

BRITISH ACTUATOR MANUFACTURER and flow control company Rotork Middle East’s purpose-built factory was opened recently in Dubai.

Situated in the Jebel Ali Free Zone, the new premises contain offices and workshops. The 600sq metre facility will provide increased local support for business throughout the Middle East.

The new facility will provide a range of valve adaptation, retrofitting, site service and asset management activity encompassing electric and fluid power actuators and associated equipment. The expansion resulted from the demand for reduced project downtime, with more scope for planned and preventative maintenance. Rotork chief executive Peter France said, “The Middle East region has always been an important market for Rotork. The new facility will enable us to respond to the needs of our customers and provide expanded services for Rotork products.”

ROCKWELL AUTOMATION HAS announced the release of two new tools to help equipment manufacturers save time when designing machinery safety systems. The Rockwell Automation Safety Automation Builder (SAB) configuration software and Safety Functions pre-engineered design documents can help users navigate the design process and apply best practices.

The SAB tool is available as a free download from the Rockwell Automation website. It guides manufacturers through the safety-system design process by providing options for layout, safety performance level analysis based on ISO 13849-1 using IFA’s SISTEMA (Safety Integrity Software Tool for Evaluation of Machine Applications) and product selection using AllenBradley safety-automation products.

Technology research and advisory firm for industry and infrastructure, ARC Advisory Group research director Sal Spada said, “Rockwell Automation’s Safety Automation Builder tool provides safety-system design guidance using the world’s broadest safety-automation portfolio.”

Traditionally, engineers needed to go through a process of printing machinery-layout drawings, drawing hard and movable guarding, identifying potentially hazardous access points and required safety functions and calculating the achieved performance level for the safetyrelated control system. The SAB software will, however, help in automating the safety-selection process to help speed system design and minimise human error. With the SAB tool, users can import an image of machinery and answer questions using a drop-down menu and help screens to identify and select the necessary safeguards. The software then compiles all product selections, generates a bill of materials and compiles necessary data to populate SISTEMA.

Rotork staff at the Dubai facility

42 Oil Review Middle East Issue Four 2013

www.oilreview.me

S10 ORME 4 2013 Innovations_Layout 1 17/06/2013 11:43 Page 43

S10 ORME 4 2013 Innovations_Layout 1 17/06/2013 11:43 Page 44

13 "$ 5* $& 1 t 30 (3

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S10 ORME 4 2013 Innovations_Layout 1 17/06/2013 11:43 Page 45

GE’S POWER CONVERSION has developed a complete electrical solution for LNG plants. The high-power system is equipped to meet the requirements of LNG operators.

Applying a system approach from the grid connection to the compressor flow, the company is offering an extended electrical package from power generation to motors including drives, generators, switchgear, transformers, UPS, MCC, harmonic filters and e-house.

The company demonstrated its complete portfolio for high requirement applications at LNG 17, the 17th Annual Conference and Exhibition on Liquefied Natural Gas held recently in Houston, Texas. The GE solution is applicable to both gas turbine-driven LNG plants as well as motor-driven LNG plants. For gas turbine-driven LNG plants, the converter-fed motors can be used as starters and as helpers of the electrical applications. The motor-driven solution uses electrical motors (synchronous or induction) powered by high-power drives based on thyristor technology or IGBT technology to drive the main refrigerant compressors.

The company has made investments in demonstrating this technology, which was tested at GE’s test bench facility in Italy. The facility is equipped with a 61MW synchronous motor and variable speed drive system designed to test centrifugal gas compressor units at full load and under extreme speed, torque and dynamic response conditions to guarantee high reliability of the overall system.

www.oilreview.me

Turbo machinery control system HONEYWELL HAS ANNOUNCED an agreement with Dresser-Rand to implement the Experion Process Knowledge System (PKS) Turbomachinery Control Solution in control applications.

Custom-engineered rotating equipment solutions provider DresserRand will embed its proprietary intellectual property in the Experion C300-20 controller to control compressors and turbines.

Earlier, proprietary or ‘black box’ technology was commonly used for turbine and compressor controls which was difficult to interface with other system components and expensive to repair.

With the Experion PKS Turbomachinery Control Solution, facilities can benefit from an open unified control platform that delivers turbine control, compressor automation, compressor anti-surge protection and general plant and safety controls. It can also consolidate plant equipment controls on a single platform, while eliminating integration problems. The open control platform can be easily maintained, if necessary, and improve process visibility and safety.

David Scheef, director of marketing, strategic business units at Dresser-Rand said, “The Experion PKS Turbomachinery Control Solution enables original equipment manufacturers like Dresser-Rand to securely deploy intellectual property in the C300-20 controller for use in rotating equipment applications.

“Many of our clients are also Honeywell customers and Honeywell has an excellent technology to replace operators’ obsolete turbine and compressor controls with a totally integrated system. The industry is moving towards increased visibility of all plant equipment and this solution will help propel us toward that goal”

Oil Review Middle East Issue Four 2013 45

Innovations

GE’s electrical solution for LNG plants

S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 46

Technical Focus

Synectics technology will help protect Shell’s huge GTL project in Qatar.

Advanced surveillance for world’s

largest GTL plant I

NTEGRATED SECURITY AND surveillance technology specialist, Synectics Industrial Systems, has developed a bespoke CCTV solution to protect the world’s largest ‘Gas to Liquids’ (GTL) plant in Ras Laffan Industrial City, Qatar.

The US$18-US$19bn Pearl GTL Project is a joint development between Qatar Petroleum and Shell. It spans 2.5 sq-km – roughly the size of New York’s Central Park. Around 52,000 personnel from more than 50 countries helped construct the plant, which is dedicated to converting natural gas into valuable cleaner-burning liquid fuels and products such as GTL gasoil, naptha, kerosene, normal paraffins and base oils. Securing this world-class energy project was of vital importance.

For Page Europa, the telecommunications project contractor with responsibility for security system specification, there were several core challenges for the CCTV system provider to meet.

The sheer size of the Pearl GTL Project presented a significant challenge. Page Europa needed a fully digital CCTV solution that would not only protect the plant area, consisting of office complexes and the vast perimeter fence (measuring 1620m x 2100m), but also onshore process areas and the unmanned offshore platforms. High-end H.264 IP encoding capability was a key requirement to enable this level of functionality for such a large site.

While two separate CCTV systems were required, one to cover the plant and the other to monitor process areas, these systems needed to be integrated to allow full access (with appropriate clearance levels) to all cameras, at any time, from any of the CCTV Operator Stations. Additionally, all cameras needed to be fully integrated with the site Access Control System (ACS) and Intruder Detection System (IDS).

The plant’s location meant that technology had to withstand temperatures of -10°C to +50°C (83°C taking into account solar radiation) and varying light conditions. Ensuring maximum coverage of key process areas also meant that surveillance equipment needed to be able to operate in potentially hazardous industrial conditions. Because it was emergency, safety and production critical, the specified system could not drop below 99.99 per cent availability or have a possible single point of failure.

Onshore camera stations needed to operate at 230V AC, offshore at 24V AC. The digital CCTV system would be fully dependent on the capability of the Telecoms LAN for transporting video streams without losing maximum resolution, real time viewing, recording and storage capabilities.

46 Oil Review Middle East Issue Four 2013

Two separate CCTV systems were required at the plant.

Photo courtesy of Shell Photographic Services/Shell International Ltd.

The sheer size of the Pearl GTL Project presented a significant challenge Because of its extensive experience of providing CCTV solutions for large scale projects in the Oil and Gas industry, and of working on previous projects in Ras Laffan, it was Synectics Industrial Systems that Page Europa turned to for a solution that would fulfil the complex brief.

Toni Partipilo, sales & proposals manager from Page Europa, explained: “Very few organisations have the range and quality of products, combined with system integration capabilities and expertise to develop an industrial solution for a project of this scale. That’s why we were keen to work with Synectics to provide security CCTV system at Pearl GTL plant.”

The solution developed by Synectics Industrial Systems enables over 300 COEX™ camera stations, protecting onshore/offshore critical process areas and equipment, as well as key locations such as site access points, office buildings, warehouse space and the entire perimeter fence, to be viewed and controlled from any of the nine specified control centre workstations.

Any camera station can also be viewed on the 42” wall display monitor connected to the Synergy XPro Video Management System and controlled using Synergy EX250 CCTV control keyboards.

All cameras, a combination of fixed and PTZ

COEX™MECH4, Pressurised Dome and COEX™FECH3 (for hazardous areas), are connected using single fibre operation to a Synectics e100 video encoder within marshalling cabinets. These enable footage to be streamed via the LAN system to the central PSN servers where all footage is recorded.

The H.264 encoding technology provides high quality CCTV footage whilst utilising the minimum amount of network storage (PSN). This in conjunction with a multicasting network solution, ensures valuable bandwidth is available for other essential site security solutions.

Certified to ATEX Standards and designed to withstand the harshest industrial and hazardous conditions, the CCTV camera stations utilise a range of technologies to ensure that plant and security protection is both effective and efficient. Day/night capability, up to 18x Optical Zoom, IR enhancement technology, Autofocus, Adaptive Noise Reduction (to eliminate streaking), and Low Light technology all ensure that the clearest picture is possible whatever the conditions.

Pearl GTL CCTV solution developed by Synectics Industrial Systems is fully integrated with the third party ACS and IDS systems, a critical component for such a maximum security site. Any incident detected by these systems generates an audio and visual alarm on the control monitors.

This alarm automatically triggers a switch in the recording profile which increases the resolution and bit rate allowing real-time recording for missioncritical incidents which is then logged in a separate

www.oilreview.me

S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 47

NEW: Brück opens Dubai Warehouse

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Technical Focus

S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 48

Value of integrating gravity gradiometry and magnetic information to refine Middle East prospects GRAVITY AND MAGNETIC data provide an added and critical dimension in oil and gas exploration, by delivering a much clearer geological picture than using seismic data alone. Gravity and magnetic enhance seismic data imaging, improve velocity models and provide a low-cost risk reduction.

Specific applications for Middle East plays include characterisation of the near-surface and the production of revised and improved velocity models in order to remove seismic static problems. Modeling salt structures, especially salt flanks that are often difficult to image with seismic data, is another typical application. Gravity, gravity gradient and magnetic data provide valuable information for any geological structures showing lateral density or susceptibility contrasts, e.g. intra-sedimentary faults, volcanics and carbonates, basement depth and sediment pathways.

Potentially ambiguous seismic interpretations can be tested and modified where required. Fault correlations can be extended between seismic lines.

Simultaneous joint 3D inversion of gravity and gravity gradient data together with magnetic data provides consistent and realistic geological solutions.

The interpretation of complementary gravity and magnetic data sets leads to a comprehensive understanding of the structural history and geological evolution of an area, a vital piece of information for any exploration program.

After the closing of the Fugro Airborne acquisition, CGG will deploy its exclusive FALCON© airborne gravity gradiometer, the only gradiometer specifically designed for airborne operations, that offers the highest possible spatial resolution and the highest signal-to-noise ratio. The experts in CGG’s

Airborne interpretation and GravMag solutions groups have 50 years of experience in acquisition, quality control, processing and interpretation of land, marine and airborne gravity and magnetic data.

CGG also offers the most comprehensive proprietary multi-client library of airborne, land and marine potential field data in the world. The database incorporates approximately 14,000,000 line kilometers of aeromagnetic data, 1,200,000 line kilometers of marine gravity & magnetic data, and 2,000,000 stations of land gravity data worldwide.

Enhancement filtering and edge detection

3D modeling and seismic data integration

Simultaneous modeling of gravity and magnetics

Saudi Aramco Energy Ventures makes equity investment SAUDI ARAMCO ENERGY Ventures LLC (“SAEV”), the corporate venturing subsidiary of Saudi Aramco, announced the closing of an equity investment into Zi-Lift AS, a developer of through-tubing deployed artificial lift systems using permanent magnet motors and magnetic transmissions.

Zilift was established in May 2009 exclusively to develop and market permanent magnet technologies for innovative artificial lift applications. It is currently developing three products: TorqueDriveTM, targeting heavy oil production and gas well deliquification including conventional and unconventional gas wells; SpeedDriveTM, targeting retrofit conventional oil wells; and KickStart, for kill fluid displacement as an alternative to coil tubing/nitrogen lift.

Zilift’s high power density products can be deployed using coil tubing or wireline deployment techniques, while delivering power efficiency and optimized production. When available, the tools will also reduce lifting costs, enabling customers to explore innovative PCP and ESP deployments in

48 Oil Review Middle East Issue Four 2013

situations and applications where none exist today. Following three years of development, the Zilift TorqueDriveTM for PCP system is undergoing qualification testing.

Ibrahim Buainain, CEO, SAEV said: “Reliable and easily deployable artificial lift systems are a priority area of technology development for Saudi Aramco.

We believe that Zilift’s technologies offer potential for substantial time and cost savings in artificial lift deployment and the potential for substantially enhancing the output from large numbers of producing wells. We are delighted to become an investor in the company”.

Iain Maclean, CEO, Zilift said: “Artificial lift has a long established history of technical development, however, significant step changes are infrequent. In contrast, Permanent Magnet Motor and Transmission technology has made significant advances in the past twenty years, driven predominantly by significant increases in magnet material performance to enable smaller machines with high power density. www.oilreview.me

S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 49

Technical Focus

S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 50

Defining the reservoir in terms of its porosity, permeability, fluid content, water saturation and behaviour is one of the pre-drilling goals of exploration and production teams with the ultimate aim to optimise reservoir production over the life of the field.

David Shanks* explains.

A new generation in reservoir

characterisation T

HERE ARE VERY few 2D measurements of anything in a well bore with the exception of temperature and micro-seismic in the reservoir.

Distributed Temperature Sensing (DTS), which uses fibre optic cables, can provide a full temperature profile. To obtain pressure, flow or fluid information however, results are extrapolated and mathematically calculated with an inferred answer, so it doesn’t go far enough to measure the reservoir directly, continuously and in real-time.

Some oil companies are now moving toward time-lapse (4D) techniques that can be used to indicate infill drilling opportunities, predict flood fronts and help avoid early water breakthroughs, despite the implicit cost and complexity of this. Seismic surveys are mostly for identification of rock formations and subsurface faults and much of the fluid analysis is also inferred from these rather than directly measured.

Knowledge of the oil rim position and thickness in particular, is critical for effective reservoir observation. To achieve maximum production it is important to be able to measure the effects of not only injection operations on a reservoir but also monitoring long-term reservoir movement and behaviour. The only alternative way to keep track of the position of an oil rim is with periodic logging surveys which can be both inaccurate and expensive.

Advances have been made in seismic survey techniques enabling much greater analysis of fluid chamber and reservoir movement. The gradual development and deployment of this type of technology has taken more than 50 years from a single point seismic source with an electronic transponder to 4D, which can map the movements, fluids and sensitivities in the reservoir.

ZTORM schematic

A clearer vision With dwindling hydrocarbon reserves and increasing demand for oil and gas, innovation in the field of reservoir characterisation is crucial to continue supply.

Reservoir geophysics combined with the latest software and reservoir characterisation techniques are bringing significant improvements to production in existing fields.

Geoscientists involved in the production environment are heavily involved in reservoir characterisation. In particular, the description of the reservoir in terms of how it has been impacted by on-going production processes. The combined use of time-lapse and multicomponent data, such as seismic, logging analysis and distributed temperature sensing (DTS) have been proven to dramatically impact and improve reservoir production over the life of the field.

Knowledge and understanding of how production processes can be enhanced and modified according to activity in the reservoir is very close to becoming a reality. Continuous fluid modelling, in real-time with high resolution, is notoriously difficult due to the range of porosity types and geometries. Determining and examining reservoir contents, fluid movements and behaviour, pressure, flow and porosity, production-related changes such as water saturation, reservoir depletion, temperature and pressure as well as locating sub-seismic resolution faults and other production barriers can be even further enhanced.

The majority of production logging and pressure measurement may be straightforward in a naturally producing well, but with around 95 per cent of the world’s oil wells unable to produce naturally, the means of examination to extraction is further complicated, thus requiring complex technology and tools.

The deployment of a pump can create problems for instrument systems as the producing zone tends to be below the pump where few analysis tools can be used while the pump is running.

-The ZTORM cable is a device which is able to respond to the fluids that surround it The size of the pump may also mean that few production logging tools can be run into in the wellbore. Essentially, this means that analysing activity below the pump is a blind exercise. The development of cable-based sensors in conjunction with Zenith Oilfield Technology’s new ground fault immune ESP monitoring system can allow complicated data to be transmitted from below an ESP. The demand for a device which can not only work below the pump and provides a real-time measurement of fluids has long been a holy grail for the reservoir engineer. A measurement technology that will measure the position of the top and bottom of the oil rim in observational wells, and will in future it is hoped allow fluid measurement below pumps, is currently being devised by Zenith Oilfield Technology Ltd, based in Scotland.

A view from the wire Reservoir characterisation models are used to simulate the behaviour of the fluids within the reservoir under different sets of circumstances to find the optimal production techniques that will maximise production. The Zenith True Oil Rim Measurement system (ZTORM) presents reservoir engineers with dynamic brine/oil and gas/oil measurements for the first time, allowing accurate observation of reservoir levels, depletion and behaviour, monitoring of steam flood applications and protection against water coning.

50 Oil Review Middle East Issue Four 2013

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S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 51

“Why is Gerard smiling?”

“Because once again he has just successfully demonstrated the Graco XP70”

XP70 benefits: TM

less material wastage = money saving no more hot-potting = labor saving no more rework = time saving

Register for your demo at XP70.graco.eu.com This picture has been taken after a successful demo at Pugliese Industria Meccanica S.r.l. in Mozzagrogna (Ch) Italy.

Technical Focus

S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 52

It is a cable-based sensor which can measure the fluid contacts anywhere along its length. It can be lowered into live observation wells using a crane and company-supplied well head equipment to allow rigless deployment.

The wellbore downhole fluid level measurement system delivers high resolution measurement for oil and water simultaneously and in real-time, and provides a new and unique measurement capability. This system is designed for observation wells at present where the fluids are settled, allowing it to measure the depth of the water and oil simultaneously. It can be used as a permanent or semi-permanent installation. The information which will be produced by the surface system is as follows: 6 Brine/oil interface level 6 Oil/gas interface level 6 Reservoir sump pressure 6 Reservoir sump temperature 6 Gas cap pressure 6 Gas cap temperature 6 Confidence level on measurement 6 Status register In general however, it should be noted that the data measured by this system is relatively simple, and is transmitted digitally from the downhole system to surface. As always the most complex information will relate to the actual behaviour of the well. In some cases it may be beneficial to reproduce the signals that are being read by the system. In this respect, the company has a full test rig in Inverurie where downhole conditions may be simulated and readings reproduced to validate observations.

The ZTORM system can be run in hole with a mobile crane on an existing observation well with perforations and can be installed on a live well. The company can provide a turnkey installation without the need for a workover rig, including a pressure gradient survey at the point of installation. This device can be employed over long periods and is designed for long service life, to allow retrieval after extended periods installed.

For observation wells with a simple cased hole the system is supplied with a surface actuated anchor, for easy deployment and retrieval.

Results from the ZTORM system show good long-term stability and accuracy of all fluid interface measurements

The ZTORM cable is a device which is able to respond to the fluids that surround it. It does this over its whole length so the cable needs to be fully immersed in the fluids that require examination. The cable is distinctively made of advanced polymer, steel and wire construction.

The electronics employed to transmit the signals from the system’s two pressure sensors are based on technology that has been in use for more than 20 years in the oil industry and has been in use in Zenith since 1994, with very high success rate.

Advanced polymers The material selection for this cable is of utmost importance to the success of the installation. In today’s industry, most tools and applications inserted into an oil well are made of steel; all the logging tools, all the pressure gauges, even the electronics have a metal housing and steel clad cable. By adopting a new approach using advanced polymers and non-metallic layers, the engineers at Zenith have been able to unlock a wide range of new possibilities for cable based sensors, which enables many technologies never previously possible in the oil business. This will challenge accepted views on materials but the company is confident it has the right mix and results so far to suggest a recipe for success.

Knowledge of the oil rim position and thickness in particular, is critical for effective reservoir observation The company worked in close partnership with an experienced Polymer research consultancy to create an advanced downhole sensor wire. Extensive study and rigorous testing was carried out on immersion at temperature, tensile strength, and reaction to different gases and polymers in hostile environments which enabled a number of prototypes to be produced.

Viability and reliability The system has been extensively proved in the test rig in the company’s headquarters, where an oil rim positioned many thousands of feet from surface can be created. This simulated oil rim can have its position moved under computer control, so the sensor systems can be fully evaluated for accuracy resolution and operating range.

Results from the ZTORM system show good long-term stability and accuracy of all fluid interface measurements, as well as extremely good resolution and sensitivity (measured as a few centimetres). The system has been developed over the last five years to improve gas/oil interface sensitivity and also changed mechanically to allow rigless deployment. The materials have been developed to suit the aggressive environment.

Providing permanent pressure gauges at the top and bottom of the sensor array gives the operator wellbore measurements, as well as level information, which also can be used to crosscheck fluid level readings from the sensor cable, including a pressure gradient survey at installation, if required.

Having proved in controlled conditions that the measurement works, the company is confident that the risks in a real installation are mostly to do with the installation mechanics and possibly the presence of foams or other complex fluid or gas conditions which may create output from the system that is more difficult to interpret.

The system is capable of measuring more than just the two fluid interfaces, and development is on-going to extend the system’s capabilities. A successful feasibility study has been carried out and the company has in fact measured a slug of oil floating up a pipe and settling on top of water 4,000 feet down a piece of wire. The system is therefore able to view moving fluids and is capable of imaging them. Several near-term field trials are in discussion with operators.

New generation of reservoir analysis In essence, ZTORM allows direct empirical measurement of the fluid in real time, taking responses directly from the different characteristics of the oil, water and gas. It is a continuous, real-time 2D tool which has the potential to run below the pump. As the ZTORM fluid level system is unique, the measurement techniques will be new to the oil industry.

52 Oil Review Middle East Issue Four 2013

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S11 ORME 4 2013 Technical Focus 01_Layout 1 17/06/2013 11:47 Page 53

Conclusion Globally, the size of hydrocarbon finds is going down at a time when demand for oil and gas is continuing to grow. In many countries, the rate of production exceeds the rate of reserves replacement. In many cases, the reserves are there; they just need to be located or extracted more efficiently. Reservoir geophysics combined with the latest software and reservoir characterisation techniques is bringing significant improvements to production in existing fields.

To continuously improve production efficiency and extend field life it is likely that the monitoring and analysis of reservoir depletion will need to be more continuous and carried out at much higher levels of detail than ever before, and this technology might be a sign of things to come. â–

David Shanks

Creating a technology like ZTORM and its future relatives will unlock more of the mysteries of the reservoir. This will be a major challenge for reservoir analysis and production engineering as it will generate information that has never been seen before.

www.oilreview.me

*David Shanks is development manager with Zenith Oilfield Technology Ltd. David Shanks has more than 20 years’ experience in permanent downhole gauge and flow and fluid measurement design and installation systems. He has also spent nine years working on novel oil field multiphase flow measurement applications and holds a number of patents in telemetry systems, flow meter and ratio tools. He is responsible for the development of new technologies and products in measurement and control of oil field production systems at Zenith Oilfield Technology. He previously worked as general manager at Ziebel UK Ltd and was managing director of his own successful oil field instrumentation business, Axon Instruments which he sold to Ziebel in 2006.

Oil Review Middle East Issue Four 2013 53

Technical Focus

However, this unique information will take oil companies, geologists and geophysicists to new territories in understanding the behaviour and characteristics of the reservoir. It may also ultimately bridge a gap between production engineers and reservoir analysts allowing a detailed, real-time visual image of how fluids migrate and flow throughout the reservoir, which is not restricted by use of artificial lift and not as expensive or complex as 4D seismic.

S12 ORME 4 2013 Technical Focus2_Layout 1 17/06/2013 11:53 Page 54

Technical Focus

Illuminating the reservoir with Silixa’s intelligent Distributed Acoustic Sensor (iDAS™) and ULTIMA™ Distributed Temperature Sensor (DTS), by Sudhendu Kashikar*

Flow profiling

on demand A

S ENERGY DEMANDS increase rapidly, the goal of energy companies is to maximise ultimate recovery in an economically sound manner. One critical capability is the accurate measurement and monitoring of production from individual layers/ perforated intervals in a multi-zone completion.

This data allows operators to optimise zonal production, improve recovery, increase production per well and reduce overall lifting costs. In spite of its importance, there is limited use of downhole flow metering, particularly in highly deviated and horizontal wells. This stems from the high intervention costs of workover and coil-tubing operations, as well as practical technology limitations, including difficulty in logging highly deviated wells and uncertainties with conventional production logging tools.

Distributed fibre optic sensing technology offers a solution for downhole production monitoring and reservoir monitoring by overcoming the cost and technology challenges encountered with traditional point sensors.

Silixa’s Intelligent Distributed Acoustic Sensor (iDAS) and ULTIMA Distributed Temperature Sensor (DTS) facilitate an opportunity for operating companies to obtain permanent, continuous

downhole flow metering. By comprehensively understanding the technical and business implications of implementing permanent monitoring using the iDAS and ULTIMA DTS, operators can thoroughly evaluate the value added by introducing this new technology to their completions.

For single point sensors such as downhole pressure/temperature gauges and flowmeters, it is necessary to predetermine where in the well the sensors are to be installed. One of the advantages of the distributed sensing is the ability to measure temperature at any point along the fibre, thereby negating the need for irreversible pre-completion sensor placement.

The emergence of iDAS, and the principle of the fibre being the sensor, opens a new potential; the ability to capture well and reservoir data along the entire length of the well. The acquired data can be used for production optimisation with detail which

The system digitally records both the amplitude and phase of the acoustic fields

Figure 1: The intelligent Distributed Acoustic Sensor (iDAS™) provides digital acoustic measurements along the entire length of single mode fibre.

54 Oil Review Middle East Issue Four 2013

would be not possible using conventional point sensors.

The operating principle for distributed sensors is as illustrated in Figure 1. A pulse of light travels down an optical fibre. A small amount of the light is naturally scattered in the fibre and returns to the sensor unit. Silixa’s iDAS utilises a novel optoelectronics architecture that uniquely measures the modulation of the backscattered light. An acoustic field around the fibre exerts tiny pressure/ strain changes onto the fibre. The iDAS measures these pressure changes at a rate of up to several kilohertz and so can be used to measure the acoustic field. The system digitally records both the amplitude and phase of the acoustic fields up to tens of kilohertz at every location and, hence, can ‘listen’ to every point along the fibre. The system can offer one metre spatial resolution with a wide dynamic range of more than 90 dB and with no cross-talk.

To enable the use of iDAS, a number of fast signal processing techniques, using coherent phase array processing, have been developed which allow analysis of the acoustic signal along the entire length of fiber and identify flow characteristics along the wellbore.

In addition, the propagation of the acoustic energy along the wellbore can be analysed in space-frequency domain (k-ω) to determine the speed of sound and, thereby, measure the fluid composition and velocity.

Field surveys were conducted on several wells offshore Norway¹. These multi-zone completions featured existing fibre installations for downhole permanent pressure and temperature gauges.

Acoustic measurements were made along the preexisiting surface and downhole fibre infrastructure using iDAS instrumentation placed in an instrument room aboard the platform. During this trial, the existing downhole sensors were disconnected from their topside instrumentation. Neither a dedicated installation of fibre nor any optimisation of the cable construction or connectors were performed.

The iDAS surveys in this study were all performed on single-mode fibres.

The oil producer was producing relatively heavy fluid and gas lift was used to help the production.

Only a minute amount of free gas was present in the fluid up to the gas lift valve.

The iDAS system can measure the phase of the acoustic signal coherently along the fibre optic cable. Therefore, it is possible to use a variety of methods to identify the presence of propagating acoustic waves.

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Technical Focus

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Digital signal processing can transform the time and space data into a diagram showing frequency and wavenumber in k-ω space. Frequency independent propagation will lead to a line in k-ω space.

Figure 2 shows the time and space signal and the corresponding k-ω space. Using the lower figure, the speed of sound can be calculated. The frequency band over which the speed of sound can be determined is more than sufficient for compositional and flow characterisation. With the iDAS system the speed of sound can be evaluated over a large section of the well and, therefore, measure the distributed variations of the flow composition and characteristics along the well. The technique is particularly powerful for determining the fluid composition of the flow - for example, gas has a speed of sound of around 600m/s whereas water has a speed of sounds around 1500m/s.

This k-ω analysis is facilitated by the unique ability for iDAS to determine the full acoustic signal (amplitude, frequency and phase).

The two lines in the k-ω space in the first and

The iDAS surveys in this study were all performed on singlemode fibres

Summary

Figure 2: The data array processing showing the ridge in a k-w plot corresponding to the acoustic waves propagating through the fluid.

third quadrants respectively correspond to the speed of sound travelling up and down the well.

These two lines can be analysed to reveal the Doppler-shifted sound speeds for upward and downward propagating sound within the fluid of interest.

Figure 3 shows the distributed flow determined in a gas injector based on Doppler shift measurements for a 30 s sampling. The determined flow speed varies with depth in the well corresponding to the change in hydrostatic pressure for a section of tubing with a uniform inner dimension and a gradually sloped well trajectory. In total the instantaneous and locally determined flow is roughly within +/- 0.3 m/s (that for this well is 10 per cent) of the actual flow speed.

Figure 3: The Doppler shift between the upgoing and downgoing speed of sound provides fluid velocity measurement.

As demonstrated, the iDAS can detect the acoustic field in the variety of oil wells surveyed and use its unique ability to capture the true acoustic field to enable detailed analysis of the acoustic signal.

There is a sufficient signal to allow further processing of the recorded acoustic field. The demonstration of clear dispersion diagrams (kplots), demonstrates both the quality of the recorded signal and the presence of propagating acoustic signals that can be used to quantify distributed composition and flow velocity along the wellbore.

The iDAS has demonstrated its capability for retrofitting to existing fibre installations. The signal quality also holds potential for developing other diagnostics techniques in the future. ■

¹ SPE 149602; Distributed Acoustic Sensing - a new way of listening to your well/reservoir; Kjetil Johannessen Statoil ASA, SPE, Brian Drakeley Weatherford International, SPE, Mahmoud Farhadiroushan Silixa Ltd., presented at the SPE Intelligent Energy International held in Utrecht, The Netherlands, 27–29 March 2012 *Sudhendu Kashikar is responsible for orchestrating Silixa’s worldwide Oil and Gas sales efforts. He is focused on delivering an integrated product and service offering directly aligned with the needs and expectations of Silixa’s diverse global customer base. Kashikar has over 20 years of experience in the upstream oil and gas business. He spent the first 20 years of his career at Schlumberger, starting as a field engineer in the Gulf of Mexico before progressing to senior sales and business development roles based in the United States, Middle East and Asia. He has extensive experience in downhole monitoring including field installations. Having managed numerous MWD/LWD/DD projects, he established and expert level in well placement, logging, monitoring including interpretation of downhole data. He holds a Master of Science in Petroleum Engineering (MS) from the University of Oklahoma and has authored numerous papers and patents.

Aquaterra Energy expands to Dubai AQUATERRA ENERGY, THE offshore engineering solutions specialist, has extended its global footprint and cemented its presence in the Middle East with the opening of a new office in Dubai.

Driving the Aquaterra Energy business in this strategic region is newly appointed sales manager Martin Bolton, who is responsible for developing new growth for the company’s products and services in the Middle East.

Bolton has held sales positions at Claxton, an Acteon group company, over the past nine years and brings with him a wealth of experience in business development. Throughout his career, Bolton has actively managed sales activities and opportunities, while also providing valuable technical and engineering scoping for clients.

During his early career, Bolton worked as a

56 Oil Review Middle East Issue Four 2013

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Field Service Engineer, Surface and Subsea Engineer and Senior Service Technician, for companies such as Vetco Gray and Dril-Quip, giving him important hands-on experience of running equipment, installation and maintenance,

and overall project completion.

Bolton’s past six years have been spent travelling the region from a base in Dubai where he has gained the essential knowledge and contacts required to secure key opportunities for Aquaterra Energy.

Patrick Phelan, managing director of Aquaterra Energy, said: “The Middle East is a strategic priority for a permanent Aquaterra Energy presence as this region presents excellent shallow water opportunities which play to our experience and strengths. Having Martin on board to establish our office in Dubai is key as he has exceptional experience in this region and his sales and business development skills will be vital in establishing the company in this important market.”

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S13 ORME 4 2013 Arabic_Layout 1 17/06/2013 12:01 Page 60

S13 ORME 4 2013 Arabic_Layout 1 17/06/2013 12:02 Page 61

‫أﺧﺒﺎر‬

‫ﻗﻄﺮ ﺗﺆﺳﺲ ﺻﻨﺪوﻗﺎً ﻟﻼﺳﺘﺜﻤﺎر ﻓﻲ اﻟﺒﻨﻴﺔ اﻟﺘﺤﺘﻴﺔ ﺑﻘﻄﺎع اﻟﻄﺎﻗﺔ‬

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‫أﻳﻠﻮل‬/‫ﺳﺒﺘﻤﺒﺮ‬ π«HQGC ...................................................................... RɨdGh §Øæ∏d π«HQGC ¢Vô©e 5 ` 2 øjOôHGC ............................................................. ÉHhQhGC Qƒ°ûahGC ¢Vô©eh ô“ƒDe 6 ` 3 áeÉæŸG ...................2013 §Øæ∏d §°Sh’ C G ¥ô°ûdG ô“ƒDeh ¢Vô©e10/2 ` 29 ‫ول‬6‫ﺗﺸﺮﻳﻦ ا‬/‫ﻧﻮﻓﻤﺒﺮ‬ »ÑXƒHGC ................... ` §Øæ∏d ‹hódG »ÑXƒHGC ô“ƒDeh ¢Vô©e13 ` 10 ¿Gô¡¶dG ............................

`RɨdGh §Øæ∏d ‹hódG …Oƒ©°ùdG ¢Vô©ŸG 27 ` 25

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S13 ORME 4 2013 Arabic_Layout 1 17/06/2013 12:02 Page 63

‫أﺧﺒﺎر‬ ,∂dòd áé«àfh .™«æ°üà∏d á«æeõdG IÎØdG ¢†«ØîJ ‫ﺳــﺎﺑـــﻚ ﺗـﺪﺷــﻦ ﻣﺼﻨــﻊ اﻟﺠُﺒﻴــﻞ‬ Ö∏¨à∏d Éeób »°†oŸG ∂HÉ°S AÓ˘ª˘Y ¿É˘μ˘eEɢH í˘Ñ˘°UGC »àdG äÉjóëàdGh ,ÉehO Iô«s¨àoŸG äɢLɢ«˘à˘M’G ≈˘∏˘Y lIójóL ¢lUôa É¡æY ódƒàJ IõØëeo IkOÉe ônÑà©oJ ɪc á«°SÉ°S’CG äÉYÉæ°ü∏d ájOƒ˘©˘°ùdG á˘cô˘°ûdG äó˘cGC .á«μ«eÉæjódG º¡JÉYÉæ°U ‘ º¡¡LGƒJ Aɢ°ûf’EGh Aɢæ˘Ñ˘dG π˘ã˘e ;᢫˘dhÎÑ˘dG äɢYɢ æ˘ °üdG ‘ ƒ˘ ª˘ æ˘ dɢ H ɢ ¡˘ eGõ˘ à˘ dG ≈˘ ∏˘ Y ,iô˘ NGC Iô˘ e ,(∂Hɢ °S) IQGO’EG ¢ù∏› ¢ù«FQ ÖFÉf ,»°VÉŸG óªfi ∫Ébh ᢠ˘«˘ ˘ë˘ ˘°üdG ᢠ˘jɢ ˘Yô˘ ˘dGh Aɢ ˘Hô˘ ˘¡˘ ˘μ˘ ˘dGh äGQɢ ˘«˘ ˘°ùdGh ø˘FGó˘∏˘dG äÉ˘Ñ˘cô˘e ™˘æ˘°üe ɢ¡˘Mɢ à˘ à˘ aɢ H ,»˘ æ˘ Wƒ˘ dG √ò˘g í˘«˘à˘J{ :∂Hɢ°S á˘cô˘°ûd …ò˘«˘Ø˘æ˘à˘dG ¢ù«˘ Fô˘ dGh .Iõ¡L’CGh ™æ°üe ¤GE áaÉ°V’EÉH ,∫h’CG ᢫˘°Só˘æ˘¡˘dG á˘jQGô◊G º˘Yó˘d ᢰUô˘Ø˘dG ∂Hɢ°S á˘cô˘°ûd Ió˘jó÷G ™˘fɢ°üŸG Úμ“ ¤GE ≈˘ ˘©˘ ˘°ùj …ò˘ ˘dG ±ó˘ ˘¡˘ ˘dG Oƒ˘ ˘Lh ™˘ ˘ eh ácô°ûdG ‘ ∂dPh ( ) Ú∏«HhôH ‹ƒÑdG äÉÑcôe ∫Ó˘N ø˘e ∂dPh ,π˘°†aGC πm˘ μ˘ °ûH ɢ ¡˘ FÓ˘ ª˘ Y ìÉ‚ ájQÉéàdG º¡JÉeÓYh º¡JÉéàæe õ««“ øe AÓª©dG ‘ É¡d á©HÉàdG á°ü°üîàŸG äÉjhɪ«˘μ˘∏˘d á˘jOƒ˘©˘°ùdG ᢶ˘Øfi ¤GE ∫ƒ˘°Uƒ˘∏˘d ÈcGC ᢫˘fɢ μ˘ eÉE˘ H º˘ gOGó˘ eGE ¿pGò˘ ˘g π˘ ˘ª˘ ˘©˘ ˘«˘ ˘°S ,Ú°ùaɢ ˘æŸG ø˘ ˘e π˘ ˘°†aGC πm˘ ˘μ˘ ˘ °ûH .á«YÉæ°üdG π«Ñ÷ o G áæjóe ∫ɪYGC ‘ É¡Yƒf øe IójôØdG äÉéàæŸG øe áYƒæàe ᢠYƒ˘ ª› ¤GE ∫ƒ˘ °Uƒ˘ dG π˘ «˘ ¡˘ °ùJ ≈˘ ∏˘ Y ¿pɢ ©˘ æ˘ °üŸG ¢†©˘ ˘ H Öfɢ ˘ L ¤GE ,Ió˘ ˘ jó÷G ™˘ ˘ fɢ ˘ °üŸG √ò˘ ˘ ˘g ∫ƒ∏M Ëó≤J ‘ º¡JóYÉ°ùeh ,IôμàÑŸG ∂«à°SÓÑdG ô˘aƒ˘j …ò˘dG ƒ˘gh ,äɢeÉÿG ¢Vhô˘Y ø˘e á˘Ø˘ ∏˘ àfl á«YÉæ°üdG äÉ©ªéàdG ᫪æJ èeÉfôH πãe ,äGQOÉÑŸG .z¥ƒ°ùdG ¤GE ÉYƒæJ ÌcGC á«fÉμeGE ™e ܃∏£ŸG ¿ƒ∏dG QÉ«àN’ ák«∏fi ämGQÉ«N ,IójóL πªY ¢Uôa OÉéjGE ≈∏Y óYÉ°ùà°S ,á«æWƒdG

‫ﻣﺸﺮوع ﻋﻤﺎﻧﻲ ﻻﺳﺘﺨﺮاج اﻟﻨﻔﻂ اﻟﻤﻌﺰز ﺑﺎﻟﻄﺎﻗﺔ اﻟﺸﻤﺴﻴﺔ‬

Êɪ©dG §ØædG IóYÉ°ùŸ á«°ùª°ûdG ábÉ£dG

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S13 ORME 4 2013 Arabic_Layout 1 17/06/2013 12:02 Page 64

S13 ORME 4 2013 Arabic_Layout 1 17/06/2013 12:02 Page 65

‫أﺧﺒﺎر‬

‫ﺳﻜﺘﻠﻨﺪﻳﺔ ﻓﻲ اﻟﻨﻔﻂ واﻟﻐﺎز‬G‫زﻳﺎدة اﻟﻄﻠﺐ ﻋﻠﻰ اﻟﺨﺒﺮة ا‬

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‫ﻋﻘﺪ أﺑﻮ ﻇﺒﻲ ﻟﻤﺠﻤﻮﻋﺔ ﺣﺒﺘﻮر ﻟﻴﺘﻮن‬ πã˘e ,Rɢ¨˘dGh §˘Ø˘æ˘dG ´É˘£˘≤˘H á˘£˘Ñ˘JôŸG äɢYhô˘°ûŸG »àdG äGÈÿG ™˘e ɢeÉ“ ,• ' ƒ˘HRô˘dG í˘£˘°S' ´hô˘°ûe ∫É› ‘ ¿ƒ˘ à˘ «˘ d Qƒ˘ à˘ Ñ˘ M ᢠYƒ˘ ˘ª› ɢ ˘¡˘ ˘H ™˘ ˘à˘ ˘ª˘ ˘à˘ ˘J IQó˘b ø˘ Y Ó˘ °†a ,ᢠ«˘ à˘ ë˘ à˘ dG ᢠ«˘ æ˘ Ñ˘ dGh äGAɢ °ûf’EG ‘ á°ü°üîàŸG äÉYhô°ûŸG ò«Ø˘æ˘J ≈˘∏˘Y á˘Yƒ˘ªÛG .zá«FÉædG øcÉe’CG ≈∏Y ¿ƒà«d QƒàÑM áYƒª› πªY ¥É£f πªà°ûjh π˘«˘ ¨˘ °ûJ Aó˘ Hh Qɢ Ñ˘ à˘ NGh Aɢ °ûfGEh OGó˘ eGEh º˘ «˘ ª˘ °üJ ≈∏Y É¡d á©HÉàdG ≥aGôŸGh ,ÖJÉμeh ,áeÉbGE áYƒª› Ú p Jô˘ jõ˘ L p «˘ æ˘ Ñ˘ e ø˘ ª˘ °†à˘ J »˘ à˘ dGh ,Ú p à˘ «˘ Yɢ æ˘ °U Ú ó˘«˘dƒ˘J äGó˘Mhh ,᢫˘æ˘μ˘°S ¿mÉ˘Ñ˘e ᢩ˘HQGCh ,ÖJÉ˘μ˘ª˘∏˘d Üô˘°ûdG √ɢ«˘e á÷ɢ©Ÿ ™˘fɢ°üeh ,∫õ˘jó˘dɢH AɢHô˘¡˘c .»ë°üdG ±ô°üdGh ákdhƒD°ùe ¿ƒμà°S ¿ƒà«˘d Qƒ˘à˘Ñ˘M á˘Yƒ˘ª› ¿GC ɢª˘c äÉÑ«cÎdG ∫ɪYGC ≈∏Y ±Gô°T’EGh IQGO’EG øY É°†jGC

≠∏Ñà ó≤Y ÚeÉCàH ¿ƒà«d QƒàÑM áYƒª› âeÉb ôμ°ù©e AÉ°ûfGEh º«ª°üàd »μjôeGC Q’hO ¿ƒ«∏e 68 Ú p Jô˘ ˘jõ˘ ˘L ≈˘ ˘∏˘ ˘Y ¬˘ ˘d ᢠ˘©˘ ˘Hɢ ˘à˘ ˘dG ≥˘ ˘ aGôŸGh ᢠ˘ eɢ ˘ bGE ôjƒ£J á£N øe Aõéc , h ɪg ,pÚà«YÉæ°U 120 ó©oH ≈∏Y ™≤j …òdG •ƒHRôdG í£°S §Øf π≤M í˘dɢ°üd ∂dPh ,»˘ Ñ˘ Xƒ˘ HGC Üô˘ Z ∫ɢ ª˘ °T k GÎeƒ˘ ∏˘ «˘ c ` ÉeOGC) ájôëÑdG ≥WÉæŸG ‘ á∏eÉ©dG »ÑXƒHGC ácô°T .(á∏eÉ©dG ,¢ù«˘fƒ˘e -õ˘«˘Hƒ˘d ƒ˘«˘fƒ˘£˘fGC ¬˘«˘°Sƒ˘N ìô˘ °U ó˘bh …ò` `«˘ ˘Ø˘ ˘æ˘ ˘ à˘ ˘ dG ¢ù` `«˘ ˘ Fô˘ ˘ dGh IQGO’EG ¢ù∏› ¢ù«˘ ˘ FQ Rõ©j ójó÷G ´hô°ûŸG ¿ÉCH ,¿ƒà«d QƒàÑM áYƒªÛ §˘ Ø˘ æ˘ dG ´É˘ £˘ b ‘ ᢠYƒ˘ ªÛG äɢ fɢ μ˘ ˘eGEh äGÈN ÈcGC ó˘MÉC˘c á˘cô˘°ûdG Iô˘¡˘°T ¤GE ∞˘«˘°†jh ,Rɢ¨˘dGh §˘°Sh’CG ¥ô˘°ûdG ‘ Ú«˘dhó˘dG ÚYƒ˘æ˘àŸG Údhɢ ≤ŸG ≈˘°Tɢª˘à˘J{ :õ˘«˘fƒ˘e -õ˘«˘Hƒ˘d ∫ɢbh .ɢ«˘≤˘jô˘aGC ∫ɢª˘°Th

S13 ORME 4 2013 Arabic_Layout 1 20/06/2013 12:17 Page 66

ADVERTISERS INDEX Company..................................................Page

Global Pipe Company................................................17

Safehouse Habitats ....................................................42

ABB Automation L.L.C ..............................................41

GRACO BVBA ..............................................................51

Saga PCE Pte Ltd. ......................................................37

ALAA Industrial Equipment Factory ......................17

Hi-Force Ltd. ................................................................15

Samson Controls FZE ................................................39

Arminox Gulf FZCO ....................................................26

Inova Geophysical Equipment Ltd. ........................11

Schlumberger/MI Swaco ............................................2

Blueback Reservoir AS..............................................18

International Exhibition Services SRL ..................62

Schlumberger Technical Services, Inc.....................6

BME Global ......................................................................

(SAOGE 2013)

Schneider Electric IT Logistic Europe ......................9

Bredero Shaw Middle East Ltd. ..............................13

Jotun Paints U.A.E. Ltd. (LLC) ....................................5

Shree Steel Overseas FZCO ....................................30

Bruck Pipeconnections BV ......................................47

Marelli Motori SPA ....................................................19

Society of Petroleum Engineers (ATCE 2013) ....31

CGG Services (SA) UAE ............................................43

Metscco Heavy Steel Industries Co. Ltd...............55

Society of Petroleum Engineers ............................49

CompAir Middle East ..................................................3

Nexans ..........................................................................21

Suraj Limited ..............................................................39

DMG World Media Dubai Ltd. (ADIPEC 2013) ....57

Oman Cement Company ..........................................35

TMK Middle East ........................................................23

Duferco ........................................................................29

PennWell Corporation ..............................................44

Trade House TMK ......................................................33

Emerson Process Management ................................7

(PetroWorld India 2013)

Trans Asia Pipeline Services FZC ..........................24

Expotim International Fair ORG. INC ....................60

Prakash Steelage Limited ........................................27

Tratos Cavi S.p.A.........................................................32

(Erbil Oil&Gas 2013)

Qatar Expo (DIOGE 2013)..........................................64

Triplefast Middle East Limited ................................45

FourQuest Energy Inc ................................................25

Rockwell Automation................................................53

Van Oord nv ................................................................67

S13 ORME 4 2013 Arabic_Layout 1 20/06/2013 12:17 Page 67

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