Oil Review Middle East 5 2013

ORME 5 2013 COVER_ORMETHREE05COVER.qxd 21/08/2013 16:22 Page 1

Vol 16 Issue Five 2013

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UK £10, USA $16.50

BG highlights Egypt investment concerns Maintenance to cut Iraqi oil exports Qatar plans energy shake-up to fuel expansion Fujairah oil storage boom continues Takreer takes the low impedance path to tank safety Options for controlling sand Industrial Internet - good news for the oil and gas sector?

CGG is offering clients in the region new integrated geological, geophysical and reservoir capabilities that is claims will bring value to many aspects f natural resource exploration, development and production.

See page 64

Lukoil targets ‘massive’ regional expansion l na o i g re or e sect h t s 97 ing ga 19 v r & Se oil ince s

16

rs

a ye

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Vol 16 Issue Five 2013

Contents

www.oilreview.me UK £10, USA $16.50

BG highlights Egypt investment concerns Maintenance to cut Iraqi oil exports

Columns

Qatar plans energy shake-up to fuel expansion Fujairah oil storage boom continues

4

Industry news and executives’ calendar

Takreer takes the low impedance path to tank safety Options for controlling sand Industrial Internet - good news for the oil and gas sector?

Analysis 10

Lukoil The Russian oil giant has opportunities across the Middle East firmly in its sights.

12

Oil Storage

Lukoil targets ‘massive’ regional expansion l na gio re ctor e th s se 7 9 ing ga 19 rv & Se oil nce si

CGG is offering clients in the region new integrated geological, geophysical and reservoir capabilities that is claims will bring value to many aspects f natural resource exploration, development and production.

See page 64

The importance of access to oil storage capacity outside the Strait of Hormuz has seen the UAE port of Fujairah become a major bunkering hub.

16

ars

ye

The Russians are coming.

See page 10.

Exploration & Production 16

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

Gas 20

Analysis

It’s been a busy period for Dana Gas, which announced record production in Egypt and the arrival of a new CEO.

22

Shale Gas

GCC countries closely monitor shale gas production as it may effect global oil prices.

Petrochemicals & Refining 28

Developments

How the demands of today’s refinery operators have created a new wave of challenges.

Exhibition Preview 37

Erbil Oil & Gas

This year’s major show in the Kurdistan Region of Iraq promises to be the biggest so far.

The world can’t get enough of the recovering nation’s oil and gas.

Technical Focus 40

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

54

Artificial Lift

Editor’s note THE RUSSIANS ARE coming, and they mean business. Russian oil giant Lukoil is considering undertaking a massive expansion in the Middle East region in the coming years as part of the company’s global development strategy, which involves increasing its foreign production of oil and gas by two and a half times its current level. Despite the fact that most of the company’s strategic assets are located in Russia, in recent years Lukoil has started to pay much more attention to its overseas expansion. Among the reasons for this is the high level of competition in Russia, limited access to promising new resources and a high fiscal burden. In addition, in recent years the company has been faced with the problem of rapidly falling production in the domestic market, despite the fact that it utilises horizontal drilling technology, which reduces the cost of production and increases well flow rates by three to four times, as well increasing the rate of recovery from oil fields. According to research conducted by the company, the conditions of production and development – as well as the geographical position of some of its foreign projects – are associated with lower production and transport costs when compared to its domestic projects.

The main focus of Lukoil in the Middle East is currently in Iraq, in particular the West Qurna-2 oilfield, the production rights for which were awarded to Lukoil in 2009. According to Lukoil’s president, Vagit Alekperov, the company plans to start production at the West Qurna-2 field in 2014.

With ever increasing well populations being produced by artificial lift, operators are looking for safer, more efficient and cost effective methods of managing their fields.

60

Storage Tank Safety

12

How to reduce the risk of a lightning fire event.

68

Sand Control Options for controlling sand infiltration.

Communications & IT 72

Industrial Internet GE’s Industrial Internet is mostly about energy efficiency, says Ian Roullier.

77

Databank/Rig Count

Arabic Section 4 6

News Analysis - Saudi Gas

The importance of access to oil storage capacity in the region has been underscored by Iranian threats to block the Strait of Hormuz. Fujairah has become a major bunkering hub for ship refuelling and is inctreasingly becoming a trading hub for petroleum products.

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

Publisher: Nick Fordham

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

Serving the world of business

Oil Review Middle East Issue Five 2013 3

News

S01 ORME 5 2013 Start_Layout 1 21/08/2013 16:27 Page 4

MENA oil exporters to grow by 2.3 per cent in 2013 The IMF has released its latest edition of the World Economic Outlook (WEO) and has revised down its projections for 2013 global growth by 0.2 per cent points to 3.3 per cent, yet again pushing back the expected recovery. The IMF’s forecasts for 2013 growth were revised down in each of its last three quarterly updates to the WEO, from a peak forecast of 4.1 per cent made a year ago. The IMF now does not expect the global economy to achieve four per cent growth until 2014.

However, according to QNB Group, with growth in the world’s largest economies slowing, the IMF outlook for 2013-14 may be too optimistic and the trend of downward revisions to forecasts is likely to continue. The euro zone continues to languish in recession with growth contracting at an annualised rate of 0.6 per cent in Q4, 2012 and expected to contract at the same rate in Q1, 2013. Growth in China has been slowing consistently and Q1, 2013 yearon-year growth of 7.7 per cent disappointed as it was below expectations of eight per cent.

Within MENA, growth in oil exporting countries has been stronger than in oil importers. However, hydrocarbon production is likely to level off in 2013, putting a cap on regional growth.

Saudi Arabian crude oil production averaged 9.5mn barrels per day in February 2013, down from its highs of over 10mn bpd in 2012 when production was ramped up to ensure oil markets remained well supplied.

MENA oil exporters are expected to grow by 3.2 per cent in 2013 and 3.7 per cent in 2014 while oil importers are expected to grow by 2.7 per cent and 3.7 per cent.

The IMF expects the US economy to expand by 1.9 per cent in 2013 and three per cent in 2014.

Maintenance work to cut Iraqi oil exports CRUDE OIL EXPORTS from Iraq will be cut by between 400,000 and 500,000 barrels per day (bpd) in September due to rehabilitation and maintenance work on the country’s southern ports, an oil official said.

The official said a third offshore terminal would be installed as well as a metering station, and that the rehabilitation will boost export capacity from Iraq’s southern ports by 900,000 bpd.

“We decided to start rehabilitation works and Basra’s oil export facilities are being upgraded maintenance of the southern oil ports and offshore terminals in September and that will cut exports by 400,000-500,000 bpd,” said the senior South Oil Company official.

Iraq’s oil exports fell to 2.328mn bpd in June from 2.484mn bpd in May due to a slowdown in Kirkuk oil shipments after repeated pipeline leakages and bad weather disrupted exports in the south.

Iraq, which has the world’s fourth largest oil reserves, has ambitious plans to increase oil exports to as much as six million bpd after decades of sanctions and war.

Qatar plans energy shake-up to fuel expansion QATAR’S NEW LEADERSHIP is expected to accelerate plans to spin off its prized asset, Qatar Petroleum, from the energy ministry to allow the world’s biggest liquefied gas producer to grow more quickly abroad at a time of rising rivalry from new producers.

Qatar’s global LNG market dominance is under threat as new producers in the United States, Australia and East Africa will flood the market with new volumes in the next few years.

Industry sources say Qatar hopes that the

4 Oil Review Middle East Issue Five 2013

www.qp.com.qa

spin off will speed up decision making.

“The rationale behind the desire for international growth is the moratorium, as the growth potential at home is quite limited”, a source at Qatar Petroleum told Reuters.

Qatar Petroleum’s growth prospects at home are severely hampered by a selfimposed moratorium on new projects to tap the world’s biggest gas reservoir, the North Field, leaving international expansion as best chance of maintaining its gas market share.

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S02 ORME 5 2013 Calendar_Layout 1 21/08/2013 16:34 Page 5

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S02 ORME 5 2013 Calendar_Layout 1 21/08/2013 16:34 Page 8

News

Executives Calendar 2013/2014 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 with sponsoring organisations as this information is sometimes subject to change

BG highlights Egypt investment concerns INTERNATIONAL GAS AND oil producer BG Group Plc said civil unrest and leadership change in Egypt had led it to review further investments in the country, as it reported a three per cent fall in second quarter net profit.

The UK-based international gas producer depends on Egypt for about a fifth of its production - a source of revenue for its expensive new projects in Brazil and Australia.

But its offshore Egyptian reservoirs are suffering decline, and the country is gearing up to consume more gas at home, increasing the possibility that BG might have to shut part of its two Liquefied Natural Gas (LNG) export operations there.

Meanwhile the ousting of President Mohammad Mursi by the military and the fact BG is owed US$1.3 billion by Egypt for domestic gas sales - up from US$1.2 billion in Q1— have heightened the company’s anxiety about investing in the country.

“Events in Egypt remain a primary concern and will continue to be so as the political, social and business environment evolves,” said BG chief executive Chris Finlayson in a results statement.

“While our offshore operations continue unaffected, higher than agreed gas volumes were diverted into the Egyptian domestic market during the quarter, impacting volumes available for LNG export,” he said.

www.bg-group.com

8 Oil Review Middle East Issue Five 2013

Aramco to sponsor automation event THE SAUDI ARABIAN section of ISA (International Society of Automation), in partnership with DMS Global, are organising the ISA Europe, Middle East and Africa Automation Conference and Exhibition from 8 - 12 December 2013, at the Sheraton Dammam Hotel & Towers, Saudi Arabia.

National oil giants Saudi Aramco have agreed to become the Titanium Sponsor for the five day event, which will be hosted under the theme ‘Experience the Future’. Saudi Aramco’s sponsorship is an important aspect in conducting the event. Along with the technical conferences, exhibitions and training, the programme also includes workshops and technology debates where regional and international industry heads, professionals and specialists will share their capabilities, ideas, visions and solution to the challenges of measurement and control in multifaceted industrial environments.

www.isa-emea-expo.org

www.oilreview.me

S03 ORME 5 2013 Analysis_Layout 1 21/08/2013 16:37 Page 9

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Analysis

Russian oil giant Lukoil has opportunities across the Middle East firmly in its sight as part of a huge expansion of its foreign interests, explains Eugene Gerden

Russia’s Lukoil targets 'massive'

Middle East expansion R

USSIAN OIL GIANT Lukoil is considering undertaking a massive expansion in the Middle East region in the coming years as part of the company’s global development strategy, which involves increasing its foreign production of oil and gas by two and a half times its current level.

Despite the fact that most of the company’s strategic assets are located in Russia, in recent years Lukoil has started to pay much more attention to its overseas expansion. Among the reasons for this is the high level of competition in Russia, limited access to promising new resources and a high fiscal burden.

In addition, in recent years the company has been faced with the problem of rapidly falling production in the domestic market, despite the fact that it utilises horizontal drilling technology, which reduces the cost of production and increases well flow rates by three to four times, as well increasing the rate of recovery from oil fields.

According to research conducted by the company, the conditions of production and development – as well as the geographical position of some of its foreign projects – are associated with lower production and transport costs when compared to its domestic projects.

Currently, the implementation of Lukoil’s foreign projects is carried out by Lukoil Overseas, the company’s operator of international projects.

According to Andrew Kuzyayev, head of Lukoil Overseas, the volume of investment in the company’s development during the next five years will be US$4-5bn annually.

Kuzyayev predicts that the share of international projects in the total production of Lukoil during the next five to seven years will grow to 20-25 per cent, with the Middle East region expected to be one of the main drivers of the company’s foreign development in the coming years.

Growth in Iraq Perhaps Lukoil's biggest hopes in the Middle East lie in Iraq – in particular the West Qurna-2 oil field, for which the rights for development were received

by Lukoil in 2009. According to Lukoil’s president Vagit Alekperov, the company plans to start production on the field in 2014.

"We have already started exploitation drilling at [West Qurna-2] with commercial production to be launched at the beginning of 2014. By 2019 we plan to reach the peak of oil production of 60mn tons per year," comments Alekperov.

10 Oil Review Middle East Issue Five 2013

Lukoil, who recently announced that it would be moving its headquarters from Moscow to Dubai, is looking to expand its presence across the Middle East region

“We have already started exploitation drilling at West Qurna-2 with commercial production to be launched at the beginning of 2014” According to the company’s plans, the volume of investment in the development of the field throughout the next 10 years will reach US$26bn, while its production will amount to 1.2mn barrels of oil per day.

West Qurna-2 is currently in the company's list of most important projects, having fought for the rights to the field since the middle of 1990s. In 1997, the already-signed contract was cancelled, however, this was not to prevent it renewal in 2009 as a result of the tender for its development, which was won by a joint bid by Lukoil and Statoil.

In May 2012, the Norwegian company left the project through the sale of its 18.75 per cent stake to Lukoil. Lukoil's current stake in the project stands at 75 per cent, with the remaining 25 per cent owned by state-owned North Oil Company. As a service contract, however, the terms of the contract have proven to be tough for Lukoil, with the Russian company only receiving fixed fees for its development and production works.

West Qurna-2 is not Lukoil's only interest in Iraq, as the company plans to participate in a tender for the development of the Nasiriyah oilfield.

The field's reserves are estimated at four billion barrels of oil, while production volumes are expected to reach 300,000 barrels per day, or the equivalent of 14mn tonnes annually.

The Government of Iraq has been trying to find an operator for the Nasiriyah project for the past three years after the failure of negotiations in 2010 of a potential development with a Japanese consortium consisting of Nippon Oil, Inpex and JGC. Meanwhile, Lukoil refused an earlier offer from ExxonMobil to purchase its stake in another Iraqi oil field, West Qurna-1, despite the potential prospects of the creation of synergy between the two West Qurna projects.

Kuzyayev says, "We have analysed all the risks and decided that due to the current implementation of West Qurna-2 project, participation in another global project without an additional partner is a big risk for us. We should admit, however, that West Qurna-1 has great investment attractiveness."

Capitalising on the Kingdom In addition to Iraq, Lukoil has big hopes in Saudi Arabia, where the company hopes to accelerate the development of Block A oil fields, which covers an area of 29,900 sq km and is located close to the world's largest oil field Al Ghawar.

The project, the rights for which were granted to Lukoil in 2004, is implemented by a joint venture of Lukoil and state oil company Saudi Aramco known as Lukoil Saudi Arabia Energy Ltd. (LUKSAR). Lukoil Overseas owns an 80 per cent stake in the venture.

The first phase of the project took five years.

During this period LUKSAR completed seismic surveys and in 2007 announced the discovery of

www.oilreview.me

S03 ORME 5 2013 Analysis_Layout 1 21/08/2013 16:37 Page 11

reserves of 85mn tonnes of oil equivalent on the Tukhman structure in the central part of the block. It would later announce the discovery of the Mushaib gas field.

To date, nine exploration wells have been drilled on the block during the period of geological survey. The company is currently preparing for appraisal works at both fields, which will take place through the drilling appraisal wells and conducting 3D seismic surveys. Appraisal works have been scheduled for completion by the end of the current year with the total cost of the project estimated at more than US$500mn.

Competition in the Caspian The Caspian region also remains in the company's sphere of interest, with Lukoil planning to accelerate its activities in Azerbaijan, which is one of the largest countries in the region in terms of oil and gas reserves.

Alekperov claims that the Russian company is currently in talks with the Azerbaijan government over the participation in new projects in the country’s oil and gas industry.

According to Azerbaijani Caspian Barrel, Lukoil currently holds a 10 per cent stake in the local Shah-Deniz gas project, which is jointly implemented by a number of companies including BP, Statoil, SOCAR and Total. In 2012, total gas production on the field amounted to 7.8bn cubic meters, of which 0.6bn cubic meters was accounted to Lukoil.

Together with its partners, Lukoil has plans to increase production at ShahDeniz, which is expected to take place as part of the next stage of the project.

It includes an additional offshore gas platform, the implementation of subsea wells and an expansion to the gas plant at Sangachal Terminal, all at an estimated cost of at least US$10bn – part of which will be invested by Lukoil.

The company’s prospects in the domestic Russian market remains cloudy in terms of new acquisitions and production volumes Egyptian expansion Finally, Lukoil is readying itself for a more active role in Egypt as part of the local long-term Meleiha project, which was one of the Russian company's first foreign projects. It entered into the project as part of the Russian-Italian joint venture Lukagip in 1995. Lukoil's share in the venture currently stands at 24 per cent, with other participants made up of ENI (56 per cent) and Mitsui (20 per cent). Proven oil reserves in the block have been estimated at more than 30mn barrels of oil equivalent.

According to Lukoil's plans, during the next few years the company will focus on the development of several oil fields that have been discovered in recent years, among which are the North and Gavaher Nada (2007), Arcadia (2010), Emery Deep (2012) and North Rose (2013).

At present, Lukoil remains the most active Russian oil company in the global oil and gas market. The company already operates in 13 foreign countries and has set ambitious goals to increase the share of foreign business in its total production up to 20 per cent in the years to come.

At the same time, the expansion of its foreign operations is an acute need for Lukoil, as the company’s prospects in the domestic Russian market remains cloudy in terms of new acquisitions and production volumes, with the volume of production on the company’s key domestic oil fields in western Siberia starting to decline in recent years.

The company does not have an access to offshore oil fields in the Russian Arctic and Far East – the rights to which have been monopolised by stateowned Gazprom and Rosneft. At the same time, in the case of the latter and in contrast to Lukoil, Rosneft has at present little presence in the Middle East – a region that has never been considered by Russia’s largest oil producer as a priority for foreign expansion.

In the case of Rosneft, three years ago the company announced its plans to start the development of the gas field in UAE’s Sharjah together with Crescent Petroleum. The value of the contract was estimated at US$630mn with first production scheduled for 2013; for various reasons, however, this project has yet to start. ■ www.oilreview.me

Oil Review Middle East Issue Five 2013 11

Analysis

S03 ORME 5 2013 Analysis_Layout 1 21/08/2013 16:37 Page 12

The importance of access to oil storage capacity outside the Strait of Hormuz has been underscored

by Iranian threats to block the world’s largest oil and gas shipping route. Among the ports outside the Strait, the UAE port of Fujairah has become a major bunkering hub for ship refuelling and increasingly is becoming a trading hub for petroleum products. Lynda Davies reports.

Fujairah oil storage

boom continues T

HE OPENING OF the Abu Dhabi Crude Oil Pipeline (ADCOP) from ADNOC’s Habshan field in Abu Dhabi‘s western desert some 400km overland to Fujairah last year, has further underlined Fujairah’s strategic importance in the global oil market.

The pipeline when it is at full capacity will allow the UAE to move as much as 1.8mn barrels of crude per day - around three-quarters of UAE’s current exports - via the Gulf of Oman, and so bypassing the Strait of Hormuz altogether. It is understood the emirate hopes to move about 1.5mn bpd via the pipeline.

A new export terminal at Fujairah serves the pipeline with storage capacity for about eight million barrels of crude. A new refinery planned to be built in the port by Abu Dhabi governmentowned Petroleum Investment Company (IPIC), which undertook the pipeline project, will give the Fujairah hub further importance.

Fujairah has seen a boom in oil terminal storage building since late 2009, with the growth receiving strong support from the Fujairah government.

According to Fujairah port data, Fujairah had some 4.07mn cubic metres (cu m) of oil storage capacity at the end of 2012. This year already has seen the start up of another new oil terminal in the port and a major expansion by an existing operator.

Fujairah port data indicates that a further two million cubic metres of oil capacity are expected to come online this year, including capacity additions from existing companies including GPS Chemoil, Socar Aurora Fujairah and Emirates National Oil Company (ENOC). The planned start-up of a further two new terminals - if they proceed as currently planned - could add another 1.5mn cu m in 2014.

There are some concerns that the tremendous investment in storage capacity at Fujairah is not justified by market demand at the location at the present time and that the storage boom could soon cause an oversupply of capacity at the port, decreasing the value of new oil storage coming online and of existing assets. Fujairah is also facing increasing competition from Oman, which is also expanding its storage facilities.

Mindful of all the new capacity coming on stream around them, at least two terminal operators are taking a cautious approach to further expansion. VTTI, a 50:50 joint venture between energy trader Vitol Group and shipping company Malaysia’s MISC Berhad, which has operated an oil storage terminal in Fujairah since 2007, is holding fire for the time being on pursuing any expansion of its 1.18mn-cu m facility.

12 Oil Review Middle East Issue Five 2013

GPS Chemoil is expanding its Fujairah terminal

VTTI’s 90 per cent owned VTTI Fujairah Terminal (VTTI FTL) recently added 250,000 square metres (sq m) of reclaimed land to its existing seafront site and currently has several business plans under study for the facility. These potential business plans can lead VTTI FTL to have additional storage of up

The storage capacity at Fujairah Oil Terminal is expected to be used both for in-house trading activities and third party rental to one million cubic metres. However, VTTI recently said the company has no approved timetable for the execution of any specific expansion plan at its Fujairah terminal.

“For us, any new development will not be a ‘copy and paste exercise’. It needs to be something that adds value,” VTTI commercial manager Aernout Boot said.

Vopak Horizon Fujairah (VHF), which operates the largest terminal in the port with capacity of 2.13mn cu m of storage and completed a 638,541cu m expansion early last year, has also said it has yet to take a decision on its proposals to build an additional one million cubic metres of storage capacity. VHF is a joint venture between Dutch

independent storage major Royal Vopak with a 33.3 per cent stake, ENOC wholly-owned subsidiary Horizon Terminals and Kuwait’s Independent Petroleum.

However, many in the industry are confident overcapacity will not be a problem given the increasing cargo volumes anticipated. In addition to its importance as a major bunkering hub, Fujairah port is increasingly becoming a trading hub for petroleum products. Singapore-based Concord Energy is building a joint venture oil storage terminal in the port with China’s Sinomart KTS Development, a wholly owned subsidiary of Sinopec Kantons Assets Group. The new facility is planned to start up in the fourth quarter of 2014.

Concord Assets Group CEO John Stuart believes there is little danger of storage overcapacity in Fujairah.

“Fujairah today is the second largest bunkering port in the world, and developing rapidly as a key logistics hub to service the GCC,“ he said, “Even though we do not expect our facility to reach commercial operations until the end of next year, we already have received strong demand for crude storage.”

Socar Aurora Fujairah, a joint venture between the State Oil Company of Azerbaijan (Socar), Swissbased Aurora Progress and the Fujairah government, started up the first phase of its Fujairah terminal in March 2012. This initial operation of what is planned to be a three-phase development

www.oilreview.me

S03 ORME 5 2013 Analysis_Layout 1 21/08/2013 16:37 Page 13

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Analysis

S03 ORME 5 2013 Analysis_Layout 1 21/08/2013 16:37 Page 14

comprises three storage tanks with an aggregate capacity of 115,000 cu m. The joint venture ultimately is targeting a 645,000 cu m capacity facility to handle more than five million tonnes per year of crude and refined products.

Socar Aurora Fujairah is working on the second phase, which will add a further 11 tanks totalling 235,000 cu m. Phase 2 is scheduled to come online in Q4 2013, while phase 3 with the final 295,000 cu m across eight tanks is targeted for completion in 2014.

Sharjah-based Gulf Petrochem inaugurated the first phase of its planned 1.2mn-cu m Fujairah Oil Terminal on 27 February. The newly-launched facilities comprise 17 tanks with an aggregate 412,000 cu m of storage and can handle class III petroleum products such as fuel oil, gas oil and cutter stock.

The new terminal sits on 112,233 sq m site, which the company says includes up to 73,269 sq m of expansion capability. Gulf Petrochem is studying a second phase of development but has yet to indicate the size of the expansion and project timeline. Some media reports have indicated that the company does not expect phase 2 to come online before 2015.

The storage capacity at Fujairah Oil Terminal is expected to be used both for in-house trading activities and third party rental. The Fujairah Petroleum Company owns a 12 per cent stake in the facility following a deal completed with Gulf Petrochem in January 2012.

GPS Chemoil, a joint venture between Singapore-headquartered Chemoil Energy and Gulf Petrol Supplies, a subsidiary of the Fujairah National Group, has begun a large expansion of its Fujairah oil storage terminal. The project is set to raise storage capacity at the facility from the current nine tanks with a total of 95,000 cu m capacity to 21 tanks with in excess of 600,000 cu m.

The soon to be expanded facility, which sits on a 580,000 sq m site, will be a multipurpose terminal, equipped to load and receive class II and class III petroleum product. The facility is connected via eight loading and receiving pipelines running from the berths at Fujairah port.

Chemoil and Gulf Petrol Supplies are expected to retain some of the additional new tanks for their own operations while the remaining capacity will be leased out to third parties. Glencore, Chemoil’s majority shareholder, and active in the trading

Gulf Petrochem is studying a second phase of development

Fujairah is also facing increasing competition from Oman, which is also expanding its storage facilities business, could also lease storage at the facility.

Glencore holds an 89.04 per cent stake in the Singapore energy group following its acquisition of Itochu’s entire 37.5 per cent shareholding in Chemoil in February 2012.

Greece-based Aegean Marine Petroleum, a supplier of marine petroleum products in the Fujairah port area, is building an oil terminal at the port. The first phase of the new facility is targeted to come online later this year, although this could not be confirmed with the company by press time. The Aegean Oil Terminal is planned to have an initial capacity of 465,000 cu m across eight tanks. Aegean Marine currently uses a floating storage facility to store the marine fuel it trades in the port area.

ENOC owns storage space with 200,000 cu m capacity in Fujairah port to store and blend fuel for domestic use and is reported to be considering adding capacity. Meanwhile, the ENOC Fujairah Distribution and Trading Terminal with 240,000 cu m storage is due to start up soon to boost the company’s refined storage capacity in the port.

Two new oil terminals by more first time investors in Fujairah port are planned to start up in 2014. IL&FS Prime Terminal FZCO (IPTF), a joint venture between India’s IL&FS Maritime Infrastructure Company (IMICL) and UAE-based Prime Terminals FZC, is targeting start-up of the first phase of a new oil terminal in the Fujairah Free Zone for Petroleum Industry, adjacent to the port, in

Phase Two is not expected to come online before 2014

14 Oil Review Middle East Issue Five 2013

early 2014. The project broke ground in September 2012 and marks IMICL’s first foray in to the storage sector in the region. The Indian company owns an 80 per cent stake in the terminal and will be its operator.

The new facility is being developed in two phases. The first phase will be built with an aggregate capacity of 333,088 cu m across 14 tanks. Phase 2 is planned to have capacity of 299,590 cu m. IL&FS Engineering and Construction Company has been selected as the EPC contractor for the terminal, receiving a letter of intent from IPTF in October. The new oil facility is built to store heavy fuel oil, gas oil and diesel, jet fuel, petrol and additives. Provision for additional features such as blending have been incorporated into the design.

The Concord Energy and Sinopec Kantons subsidiary Sinomart joint venture terminal is on track to start commercial operations in the port during Q4 2014, according to Concord Energy Assets Group CEO John Stuart.

Concord and Sinomart each own a 50 per cent stake in the planned new facility, but at the start of commercial operations Concord said it will reduce its equity to 38 per cent.

The planned facility, known as Fujairah Oil Terminal (FOT), will be built with a capacity 1.155mn-cu m capacity. Concord confirmed the expected investment in the project will total about US$360mn. FOT reached financial closure in February with a consortium of six international banks for the provision of a US$252mn senior debt facility for the project. Construction got underway in late February. Rotary Engineering is the main EPC contractor for the project.

The main products expected to be handled at FOT will be crude oil, fuel oil, gas oil and gasoline.

The facility will also offer additional services such as product mixing, blending and heating.

Stuart said Concord expects to utilise between 200,000 and 250,000 cu m of the terminal’s storage capacity with the remainder taken by third parties. He added that letters of intent had been signed by third parties but could not provide details. Stuart did not comment on how much space would be utilised by the company’s Chinese partner.

“The FOT facility is extremely flexible and offers storage capacity not only to meet the high existing demand for bunkers, but also crude storage and crude blending plus significant products for finished products. Even though we do not expect our facility to reach commercial operations until the end of next year, we already have received strong demand for crude storage,” Stuart said. ■ www.oilreview.me

S04 ORME 5 2013 E&P_Layout 1 21/08/2013 16:49 Page 15

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Cooper Energy discovers hydrocarbons offshore Tunisia COOPER ENERGY HAS announced that it has found a hydrocarbon presence at the Hammamet West-3 gasfield, located offshore Tunisia.

Hammamet West-3 is located 1.6km east of Hammamet West-2, in a water depth of 54 metres. The objective will now be to drill and test a highlydeviated wellbore through the naturally fractured Abiod Formation reservoir to confirm oil productivity, company sources have said.

The gas well has currently commenced drilling the horizontal side-track section in the primary target Abiod Formation limestone from 3,011 to 3,167 mMDRT. The maximum total gas level recorded was 37 per cent, with onsite gas compositional analysis indicating the likely presence of oil.

Ultraviolet fluorescence was also observed in the drill cuttings over the interval 3,060 to 3,092 mMDRT, which indicated the presence of oil. The drilling mud weight at the time of the gas influx into the wellbore was 10.6 pounds per gallon (ppg) and it has been raised to 11.8 ppg, sources added.

Hector Gordon, executive director of Cooper Energy, said, “Although the drilling of Hammamet West-3 has taken longer than expected, the shows encountered in the horizontal well section are encouraging and, at this stage, appear to validate the pre-drill reservoir model. The best fractures identified by pre-drill seismic studies are yet to be encountered and we look forward to drilling these in the coming days. When the horizontal well section is complete, the joint venture may decide to conduct a production test which could take another 20 days.”

Apache announces seven oil and gas discoveries in Egypt APACHE CORPORATION HAS announced that it has made seven oil and gas discoveries across Egypt’s Western Desert.

The first discovery - Riviera SW-1X - test-flowed 5,800 barrels of oil and 79,287 cubic metres (cu m) of gas per day from a Lower Bahariya sand with 7.3 metres of net pay.

Another find - the Narmer-1X - is a stratigraphic trap that is separated from the Neilos oil field located 8km to the east.

Thomas Maher, vice president of Apache’s Egypt region, said, “These seven discoveries are located in four different geologic basins and six different concessions.

“The Faghur Basin yielded four of the discoveries with one each in the Shushan, Matruh and Abu Gharadig Basins.

All seven discoveries have been tested and Riviera SW-1X is already producing. Our exploration and development programme in Egypt continues, with an average of 27 drilling rigs operating during the second quarter.”

The Riviera SW-1X well, located in the WD 30 Development Lease, is 2km south of the Riviera field, which also produces from the Upper Bahariya and Abu Roash formations.

The Narmer-1X and the Neilos field are part of an emerging Paleozoic play. Located in the Faghur Basin and the Khalda Offset Concession, Narmer-1X well encountered 25 metres of net pay in Paleozoic-aged sandstone and testflowed approximately 1,200 barrels of oil and 11,326 cu m of gas per day with a trace of water.

The Jade N-2X well, located 2.4km to the northeast of the Jade field in the western Matruh Basin within the Matruh Development Lease, encountered 10 metres of net pay in the Cretaceous-aged Alam El Buieb 3G sandstone.

The zone was perforated and tested over a 22-metre interval, producing up to 146 barrels of condensate and 3.1mn cu m of gas per day.

The WKAL-T-1X well, located 5.6km due south of the nearest production in the Tell field within the West Kalabsha Concession in the Faghur Basin, logged a total of 9.7 metres of net pay in the Safa formation. The well was tested in one of three zones of Upper Safa sandstone that flowed 2,900 barrels of oil and 79,287 cu m of gas per day.

The WKAL-N-3X appraisal well, also in the West Kalabsha Concession, successfully extended the WKAL-N

field to the west. The well flowed on test at a rate of approximately 3,500 barrels of oil and 90,613 cu m of gas per day from the Safa Formation.

The SIWA-R-1X well, located in the Siwa Concession in the Faghur Basin, tested 1,900 barrels of oil per day from the Safa sandstone. The well encountered 22 metres of net pay with the lowest known oil corresponding to the mapped structural closure.

The Buchis W-2X well was drilled in the Buchis Development Lease on the north-eastern margin of the Faghur Basin. The well tested a three-way closure adjacent and up-thrown to the Pepi oilfield with multiple Cretaceous, Jurassic and Paleozoic objectives. It encountered 13.4km of stacked pay in the Cretaceousaged Alam El Buieb formation and additional pay in the Paleozoic-aged Zeitoun and Basur formations. The well tested approximately 1,700 barrels of oil per day from the AEB-3D sandstone.

The Falak NW-1X well, drilled in the Khalda Development Lease on the northern flanks of the Shushan Basin, logged 34.7 metres of stacked net pay in the Safa sandstone. Apache tested 1,200 barrels of oil and 1.7mn cu m of gas per day from multiple Safa sands. Falak NW1X is 4.8km south of the Shams field.

Drilling and completion costs for all the wells were estimated to be US$30.1mn.

Apache has a 100 per cent contractor interest in the all the discoveries and owns, in total, 9.7mn gross acres in the North African country.

DNO International’s Tawke well hits 25,000 bpd DNO INTERNATIONAL HAS announced that its first horizontal well at the Tawke oilfield in Kurdistan Region of Iraq was flowing at the rate of 25,000 bpd.

The Norway-listed oil and gas company reported that the Tawke-20 well’s production is at a record high since the most productive vertical well in the Tawke field is

The company operates the Tawke field with a 55 per cent interest

16 Oil Review Middle East Issue Five 2013

currently flowing at an average rate of 10,000 bpd.

Bijan Mossavar-Rahmani, chairman of DNO International, said, “Our next task is to optimise production from Tawke-20 while assessing the potential of horizontal wells in terms of drilling efficiency, well recovery factor and overall Tawke field output capacity.”

A second horizontal well — Tawke-23 — was currently being drilled while preparations were also underway to start on a third horizontal well — Tawke21, Rahmani added.

In June 2013, DNO International also reported that oil was discovered at its Tawke-17 well, which tested at a rate of 1,500 bpd of 26 to 28 degree API crude from an Upper Jurassic reservoir underlying the field.

The company operates the Tawke field with a 55 per cent interest. Genel Energy has a 25 per cent stake while the Kurdistan Regional Government holds the remaining 20 per cent. www.oilreview.me

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Kuwait discovers new oil and gas field KUWAIT OIL COMPANY (KOC) has announced that it has discovered a new oil and gas field onshore Kabed, close to the Manageesh oilfield.

Hashem Sayed Hashem, chief executive officer of KOC, however, gave no estimates of the reserves in the field located in western Kuwait.

Organisation of the Petroleum Exporting Countries (OPEC) member Kuwait is currently pumping around three million barrels per day and is expected to have about 100bn barrels of crude reserves.

According to Kuwait's Ministry of Oil, the Middle East country has earmarked around US$100bn to be invested over the next five years on several oil projects, including the building of a large refinery and the upgrading of two existing ones.

The investment will likely form part of the state's long-term plan to boost oil production capacity to four million barrels per day by 2020.

The country’s current capacity is almost three million barrels per day with an additional 200,000 bpd produced from the divided zone shared with Saudi Arabia.

Kuwait reportedly holds the world’s sixth largest oil reserves and is one of the top 10 global producers and exporters of total petroleum liquids.

According to a media report, as of January 2013, Kuwait’s territorial boundaries contained an estimated 102bn barrels of proven oil reserves, roughly six per cent of the world total.

Gulf Keystone spuds Shaikan oil well in Kurdistan Region of Iraq GULF KEYSTONE HAS ANNOUNCED that the onshore Shaikan-10 oil well located in the Kurdistan Region of Iraq has been spudded, with production expected to commence soon.

In June this year, the independent oil and gas firm received approval from the regional government for its development plan for the Shaikan field.

The Shaikan-10 well is supposed to be the start of the Region’s development campaign, which will see at least three rigs involved.

Production operations for the newly-commissioned Shaikan production facility (PF-1) will also begin shortly, company sources said.

Shaikan-10 is expected to be tied to a second Shaikan production facility (PF-2), which is currently under construction, and will have an initial capacity of 20,000 bpd. Shaikan-2 and Shaikan-5 wells, which are already in production, will also be tied back to PF-2.

PF-1, when combined with PF-2 later this year, will allow the company to achieve its immediate short-term production target of 40,000 bpd.

Todd Kozel, chief executive officer of Gulf Keystone said, “The company is now fully permitted to commence production from the Shaikan field and this represents a key milestone in the company’s growth.”

The company plans to boost output from the field to 150,000 bpd within the next three years and is aiming for production to top 250,000 bpd by 2018.

Situated about 85km north-west of Erbil and covering an area of about 283 sq km, Gulf Keystone had previously estimated the Shaikan field held 13.7bn The Shaikan-10 well is supposed to be the start of barrels of gross mean the Region’s development campaign, which will see at least three rigs involved oil-in-place. www.oilreview.me

Oil Review Middle East Issue Five 2013 17

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OMV says no impact from Libya strikes AUSTRIAN OIL AND gas group OMV said its Libyan operations were not affected by recent strikes that shut down export terminals and oilfields.

"We see very little impact on OMV of the strikes," Jaap Huijskes, head of OMV's exploration and production operations, told a news conference, adding that OMV's operations were concentrated in the west of the country, which is not affected.

"At the moment it's fully on," he said.

OMV's Libyan operations account for some 10 per cent of the company's total production when running at full strength.

The outages at ports and fields caused by striking employees and jobless people demanding work have brought the worst disruption to OPEC member Libya's oil industry since the civil war in 2011.

Meanwhile, surprisingly strong refining and marketing results helped take the sting out of a steeper-than-expected drop in Q2 underlying profit at OMV. OMV said its results were hurt by lower sales volumes and crude prices, a weak dollar and write-offs, mainly in the exploration and production areas on which it is focusing OMV said lower sales volumes in Libya, Britain and New Zealand hurt its profits, as had exploration expenses that rose 72 per cent to US$138mn, mainly due to write-offs in Tunisia and the UK and increased seismic activities in Norway.

Its upstream exploration and production business, which it is expanding, reported disappointing results, as did its gas and power segment, but its downstream refining and marketing operations reported a 24 per cent rise in underlying profit.

OMV said marketing - which includes the filling stations it is selling off - had made a strong contribution thanks to better cost positions and higher margins in retail.

Petrel acquires stake in Iraqi licenses PETREL RESOURCES REPORTED that it has agreed to buy a 20 per cent holding in Amira Hydrocarbons Wasit, which holds a stake in exploration and production licenses in the Wasit province of Iraq.

Petrel said the move will strengthen its position in Iraq where it has been active since 1999. The acquisition equates to a five per cent carried interest through to production in licenses operated by Oryx Petroleum in Wasit province. Petrel added that it has also been given a right of first refusal to participate in future exploration and production www.petrelresources.com licenses in the Iraqi provinces of Muthanna, Karbala, Babil and Najaf.

Petrel managing director David Horgan commented in a company statement: "We are delighted to announce the expansion and diversification of our exploration portfolio with this acquisition. Petrel has a long-standing interest in Iraq. Following the recent farm out of our Irish acreage, the acquisition refocuses our efforts on one of the world's premier hydrocarbon basins.

"The addition of Amira's assets to our portfolio and the joint venture with the Kayablian family provides our shareholders with greater exposure to the world class hydrocarbon potential in Iraq."

DNO International signs onshore oil block deals in Yemen and Oman DNO INTERNATIONAL HAS announced it has been selected as a bidder for Yemen’s onshore Block 84 and has also entered into a farm-in agreement for Oman’s onshore Block 36.

DNO Yemen said it has been awarded a 59.5 per cent participating interest, 70 per cent paying interest and operatorship of Yemen's Block 84, while Turkeybased Dogan Enerji Yatirimlari Sanayi ve Ticaret has been awarded a 25.5 per cent participating interest and a 30 per cent paying interest.

State-owned Yemen General Corporation for Oil and Gas will have a 15 per cent participating interest, DNO said.

The partners are expected to acquire a new 3D seismic system and drill two wells during the first exploration period.

Block 84, which covers a surface area of 731 sq km, is located in the MasilaSeiyun Basin adjacent to Block 14, where more than one billion barrels of oil have

already been discovered. The company already holds interests in five onshore Yemen Blocks, two of which - Blocks 43 and 47 - are also located in the same basin.

The Block 36 farm-in agreement provides for the transfer of Allied Petroleum Exploration’s 75 per cent participating interest and 100 per cent paying interest to DNO Oman. The company will assume operatorship and acquisition of new 2D seismic data, along with the drilling of two oil exploration wells, company sources said.

The block is located in the Rub al Khali Basin and covers a surface area of more than 18,000 sq km. Two exploration wells previously drilled in the block have confirmed the presence of source rock in the basal Silurian hot shale, an organic-rich shale that has been responsible for the majority of the oil and gas fields discovered in the Middle East and North Africa.

Lebanese Cabinet set to pass oil and gas decrees for exploration projects THE LEBANESE CABINET is expected to hold a session within the coming weeks to approve two key decrees required to proceed with oil and gas exploration projects offshore Lebanon, according to the country's Energy Ministry Gebran Bassil, Lebanon's energy minister, said, “I have found the responsiveness, understanding and readiness to go ahead in this issue as rapidly as needed.”

The decrees demarcating the 10 maritime exploration blocks and establishing a revenuesharing model must be passed by the Cabinet

18 Oil Review Middle East Issue Five 2013

before any oil and gas contracts can be awarded.

“Passing the decrees is critical for Lebanon to adhere to international commitments toward major international companies that have invested in the country,” Bassil added.

Lebanon had officially launched the first oil and gas licensing round in May this year and officials have been since saying that any delay in issuing the decrees could postpone the offshore drilling and exploration process.

Forty-six international energy companies had

Lebanon officially launched the first oil and gas licensing round in May this year

prequalified earlier this year to bid for offshore hydrocarbon exploration contracts in Lebanon.

www.oilreview.me

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Gas

It’s been a busy month for Dana Gas, which announced record production in Egypt and a new CEO.

Dana Gas achieves record

production in Egypt D

ANA GAS, THE Middle East's leading regional private sector natural gas company, announced that it has achieved record production in 2013 in Egypt of 39,000 boepd, including 190 mmscfd of gas and 8,500 barrels of liquids per day.

The company has made substantial capital expenditure investments to its Nile Delta operations over the last 18 months. These include new compression facilities, new fields being brought on stream and work to increase its numerous gas plants throughput.

As a result of investments made since February 2012 production levels have reached a peak of 39,000 boepd, an increase of 13 per cent over the year 2012. The average output year-to-date has been 34,000 boepd.

Dana Gas is among the most active oil and gas investing companies in the region Monitoring developments The company’s core operations in the Nile Delta and its Egyptian Bahrain Gas Derivatives Company (EBGDCo) Natural Gas Liquids extraction plant in Ras Shukheir have not been impacted by the current events in Egypt. However, the company continues to closely monitor developments.

Dana Gas announced the Begonia-1 discovery on 30 June and has submitted a proposed Development Plan to the Egyptian authorities as part of a Development Lease application. The submission remains on track and following approvals, gas from the Begonia-1 will be tied into the existing gas gathering and production system.

Dana Gas continues to engage with relevant government authorities regarding its overdue receivables and its future capital expenditure plans.

It welcomes and actively supports the government’s desire to increase local hydrocarbon production in order to meet growing domestic demand.

Discussions of fiscal support by the international community will also play a significant role in addressing investment decisions by key international investors. During Q1 2013, Dana Gas collected US$41mn with a 100 per cent revenue collection.

A Dana Gas spokesman said: “Our Egyptian operations continue to perform well despite the difficult fiscal environment oil and gas companies have faced in the country over the last two years.

20 Oil Review Middle East Issue Five 2013

www.danagas.com

We have made four successful discoveries over the last year and increased our local production significantly.

“The recent important announcements of significant financial support for Egypt’s from a number of GCC states coupled with the government’s desire to increase local gas production dramatically, is favourable to companies such as ours.

“We are also talking with the government to resolve the outstanding receivables situation as quickly as possible. In addition, we have planned a multi-well appraisal drilling programme for the second half of 2013 and we hope to be able to implement this successfully.”

Active Dana Gas has a successful track record of gas discoveries in Egypt over the last six years and in June 2013, announced its 25th discovery with the Begonia-1well in the Nile Delta. Total investments

by Dana Gas in Egypt have exceeded US$1.8bn.

Dana Gas is among the most active oil and gas investing companies in the region and has grown to become the sixth largest gas producer in Egypt. The company remains committed to making

investments that will bring benefits to both the company and the country.

Meanwhile, Dana Gas has announced the appointment of Dr Patrick Allman-Ward as the new Group CEO for the company with effect from 1 September 2013.

The incoming CEO Dr Allman-Ward is an accomplished international energy executive with more than 30 years of experience in the oil and gas industry, in many senior positions including in the Middle East and the Gulf Region in particular.

He also brings with him an in-depth knowledge of Dana Gas as the current general manager of Dana Gas Egypt, having joined the company in 2012 after a successful career with Shell International.

Through his responsibilities in managing all aspects of Dana Gas’ operations in Egypt, including exploration, production, business development and government relations, Dr Allman-Ward successfully achieved new exploration discoveries, increasing production and developing new business opportunities.

He will continue as general manager for Dana Gas Egypt until a suitable replacement has been found. ■ www.oilreview.me

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Gas

GCC countries closely monitor production as it may affect global oil prices, Mohammed Al Asoomi told Gulf News.

Shale gas development

divides opinion T

HE ISSUE OF shale gas oil production still raises controversy, especially in European countries, both in terms of its impact on future energy supplies and oil prices as well as its harmful environmental effects. Thus, environmental organisations warned of the risks that shale gas production may pose to the natural environment and called for ceasing it.

The stands by European countries have varied with regard to shale gas production. It is imperative here to point to the statement made

by French President Francois Hollande on Bastille Day when he ruled out shale gas exploration under his administration.

Harmful emissions Hollande was quoted as saying: “As long as I am president, there will be no exploration for shale gas in France” which means there will be no shale gas exploration in the upcoming three years of his first term, or eight years if he is re-elected.

On the other hand, Britain provides massive facilities to companies operating in the shale oil and gas production; it recently decided to reduce taxes on the production of shale gas at a significant percentage from 26 to 30 per cent, which is one of the world’s lowest tax rates on gas production, despite protests by

environmentalists and warnings about harmful gas emissions.

Meanwhile, the process of shale gas production is progressing rapidly in the United States, which has turned into a gas exporter thanks to the rapid development of gas production in the past few years. Unlike the USA and Britain, Germany and Japan are reluctant as environmental concerns still constitute an obsession for decision-makers in the two countries.

In fact, this heated debate is justified as these countries need to diversify their energy sources and reduce their dependence on exports from abroad, especially from the volatile Middle East. Besides that, breaking and smashing rocks will have disastrous environmental consequences represented in air pollution due to gas leak and poisoning of the groundwater as well as earthquakes measuring up to five (on the Richter scale) because of the way the production process is carried out, leaving spaces and causing pressure on the Earth’s layers.

Meanwhile, the process of shale gas production is progressing rapidly in the United States Does shale gas production pose environmental risks?

Controversy Although the GCC countries may not have to resort to oil and gas production due to their large reserves and the high cost of shale gas production, they must be closely watching and monitoring the controversy over shale gas production, which may affect oil prices in global markets. This may lead oil prices to drop - a fact that has already happened when gas prices saw a big drop after the US doubled its shale gas production.

For other developing countries, including the non-Arab ones, it seems that despite the availability of shale oil and gas production, most do not have the funds necessary to invest in this area in spite of the high demand for energy. This simply means that shale oil and gas production will be limited to the rich countries, which have financial capabilities at present.

Major discovery They include some emerging countries such as China, India, Brazil and South Korea, where environmentalists apply strong pressure, as is the case in Europe and the USA, which will help in the expansion of gas production.

The world is on the threshold of a major discovery in energy production, thanks to technological development. If developed countries manage to take final decisions and align their stands with environmental organisations, there will be major effects on the energy industry. But, if these organisations are able to hinder expansion of production, these effects will be less.

Through this gap between the French and British positions as well as other unclear European positions, it is obvious that this battle between supporters and opponents of the shale oil and gas production will be long and complicated.

This is especially because environmentalists have become influential players who cannot be ignored in elections in European countries.

The US Secretary of Energy was quoted as saying that the shale oil and gas production will change the form of energy trading and will create many geo-political implications. ■

*The writer is a UAE economic expert and specialist in economic and social development in the UAE and the GCC countries.

22 Oil Review Middle East Issue Five 2013

www.oilreview.me

S06 ORME 5 2013 Gas News_Layout 1 21/08/2013 16:56 Page 23

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S06 ORME 5 2013 Gas News_Layout 1 21/08/2013 16:56 Page 25

GDF Suez supplies Dubai with liquefied natural gas cargo

Siemens signs power plant deal with Saudi Aramco

“This new LNG delivery is in line with GDF Suez' ambition in high growth regions, especially in the Asia Pacific basin and in the Middle East,” the company said.

GDF Suez has entered into a deal with India for the shipment of nearly one million tonnes of LNG through 2014.

The company, which is the main LNG importer in Europe operates a fleet of 17 LNG carriers and has a significant presence in regasification terminals around the world.

Gas

FRENCH ENERGY COMPANY GDF Suez has announced that it will begin to deliver Liquefied Natural Gas (LNG) to Dubai.

The company announced that it has delivered its first cargo in the LNG carrier 'BW GDF Suez Boston' to the Dubai Supply Authority's Jebel Ali terminal .

GDF Suez, whose headquarters are based in Paris, is able to adapt to tap into gas sectors in the Middle East and Asia-Pacific region, it said.

The company said that the ship had the ability to load 4.8mncf, with the delivery arriving on 4 August.

GDF said it has delivered its first cargo of LNG to Dubai

By 2016 the French company said it aims to deliver more LNG to its regional partners in Asia.

xxx

SIEMENS HAS ANNOUNCED that it has received an order for power plant components from Saudi Aramco.

The US$977.8mn contract from Siemens is for the manufacturing and supply of components for a combined cycle power plant to be built in Saudi Arabia, the company said in a statement.

The power station is expected to deliver electricity to the Jazan Industrial city area in and to the refinery of Jazan, where process steam will also be delivered.

According to Siemens, the refinery-based plant will use advanced technology for the refinery residue gasification process to help preserve the country’s energy resources.

“Our flexible, efficient and proven technology will further contribute to support Saudi Arabia,” said Michael Suess, member of the managing board of Siemens AG and CEO of the energy sector.

Golar LNG wins Kuwait contract GOLAR LNG HAS announced it has entered a US$213mn deal to provide a floating storage and regasification unit (FSRU) to the Kuwait National Petroleum Company (KNPC) at Mina Al Ahmadi.

The New York-listed vessel owner has signed a five year agreement to provide its newbuild FSRU Golar Igloo for the Liquefied Natural Gas (LNG) project at Mina al Ahmadi.

The five-year contract covers the 170,000-cubic metre newbuild Golar Igloo for nine months of every year and the vessel is due for shipment by Samsung Heavy Industries in Q4 2013.

Golar LNG CEO Doug Arnell said, "As this is a five year charter the vessel will be offered to Golar LNG Partners L.P. to acquire providing for another potential acquisition.” www.oilreview.me

Oil Review Middle East Issue Five 2013 25

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Gas

Ametek wins Al Hosn project contract AMETEK PROCESS INSTRUMENTS has been awarded a US$4.6mn contract to supply UV process gas analysers for the Abu Dhabi Gas Development Company’s (Al Hosn Gas) Shah Gas Field project. The analysers will be used in the Sulphur Recovery Units (SRU) and Tail Gas Treating Units (TGTU), expected to be the largest complex of its type in the world.

Saipem, the project management company, apparently selected www.ametekpi.com Ametek because of its extensive experience in sulphur recovery operations worldwide and the performance of its analysers on similar projects.

The US$10bn Shah Gas Field project is among the largest green field gas development projects ever undertaken. It is expected to process approximately one billion cubic feet per day (bcf/d) of sour gas into 0.5 bcf/d of usable gas.

26 Oil Review Middle East Issue Five 2013

Dana net profit falls by 45 per cent in Q2 DANA GAS HAS announced that its Q2 net profit dropped after prices for oil and sales of liquefied petroleum gas fell.

The Sharjah-based energy company recorded a net profit of US$27.2mn, the company said in a statement.

According to Dana Gas, profit fell by 45 per cent compared to the same period last year.

“The main reason is the LPG production in Kurdistan as well as oil prices,” Rashid Al-Jarwan, acting CEO of Dana Gas stated.

The company said that last month its total spending in Egypt was more than US$1.8bn and it had achieved record production this year in Egypt of 39,000 barrels of oil equivalent per day (boepd).

The company has made a lot of capital expenditure investments to its Nile Delta operations over the last 18 months; including new compression facilities, new fields being brought on stream and work to increase its numerous gasplants throughput, it said.

Following investments made since February 2012, production levels have increased by 13 per cent over 2012.

The company reported an average output of 34,000boepd, with fuel sales rising in Iraq after a production facility begun last month and may benefit from higher sale prices for gas in Egypt if the government raises the cost to buyers.

“Good progress is being made on our drilling programme in Egypt. In Kurdistan, we have completed the reconstruction of the loading bay which will enable resumption of LPG and enhance revenue,”commented Rashid Al Jarwan, acting CEOof Dana Gas. The company has now continued production of liquefied petroleum gas in the Kurdistan Region of Iraq after an explosion there halted output last year.

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S07 ORME 5 2013 Petrochemicals Feature_Layout 1 21/08/2013 16:59 Page 27

Petrochemicals & Refining

S07 ORME 5 2013 Petrochemicals Feature_Layout 1 21/08/2013 16:59 Page 28

The demands on today’s refinery operators have created a new wave of challenges. More and more, refineries are requesting a single toolset that rationalises production throughput and quality while simultaneously managing the intricacies of energy demand and creation.

Achieving business and operational success

by optimising refining T

HE DEMANDS ON today’s refinery operators have created a new wave of challenges. More and more, refineries are requesting a single toolset that rationalises production throughput and quality while simultaneously managing the intricacies of energy demand and creation.

The push for such a solution is understandable.

There are many easily understood benefits to a holistic approach to refinery-wide optimisation.

With these solutions in place, we’ve seen refining companies add from US$0.25-0.40 per barrel - and often more - to the bottom line margin at each refinery. What this can mean for a highly complex, 100,000 barrels per day (bpd) refinery, is as much as US$15mn per year in additional benefits, with the value rising proportionately when considering the refinery’s throughput and complexity. To respond to the industry’s changing needs, Invensys Operations Management has developed a solution set called Refinery-wide Performance Solutions.

There are many benefits stemming from a holistic refinery-wide approach, which can be broken down into four key drivers: measurement, empowerment, control and optimisation. These drivers help define the solutions’ main capabilities, including: 6 Improved mass balance accuracy across the refinery (Measure) 6 Model-based performance monitoring to improve personnel/operations effectiveness (Empower) 6 Optimal regulatory and advanced process control (APC) (Control) 6 Unit and refinery-wide optimisation for agility and responsiveness to changing market conditions (Optimise) 6 Evaluate and adjust energy production and utilization (Empower and Optimise) 6 Enable optimal refinery planning and scheduling (Measure and Empower) 6 Provide ready and timely access of performance data to all stakeholders (Measure and Empower) Identifying and removing faulty or inaccurate data from the plant system before it can negatively impact a refinery’s operations and profitability is a critical but often overlooked area of business process improvement. There are many benefits of improved and more accurate data including a better mass balance around a process unit or refinery and better identification of performance metrics such as material losses, emissions, equipment performance.

Improving this accuracy is a core objective of

28 Oil Review Middle East Issue Five 2013

Better data can reap substantial benefits for customers

Invensys’ Refinery-wide Performance Solutions. We have seen many customers reap substantial benefits from having better data, like a major refining company in North America which used this component of the overall solution to analyse more than 300 flow metres across one of its refineries.

Using the Mass Balance Module within the Invensys Refinery-wide Performance Solution set, the company saw a wide range of improvements such as: 6 Achieving tighter unit mass balances for yield, energy and profit monitoring 6 Identifying metres in gross error very quickly 6 Reducing the number of faulty metres from 25 per cent to less than five per cent 6 Achieving a satisfactory heat and material balance across the refinery as a starting point for the optimisation process 6 Providing more accurate mass flows to the accounting team to assist with monthly mass balance closure and to the site business planning group to help with the LP monitoring tool Integrating financial and economic data alongside process information is a necessity in achieving optimal refinery operations. Therefore well-run and profitable refineries rely on having staff knowledgeable of the process from both a technical and business perspective, armed with the right tools to make informed decisions. Access to such knowledge equips staff with ability to preemptively head off costly unplanned disruptions and shutdowns.

Invensys’ model-based performance monitoring system uses rigorous engineering models and combines process information with real-time

financial and economic data together with the derived performance measurements to create quantifiable and actionable information. This translates into continuous performance improvement by informed and thereby empowered frontline personnel, armed with an understanding of the financial performance of current operations and the impact of driving operations to a higher and more profitable state.

The applications included in this system are: crude pre-heat train monitoring and fouling calculations; compressor and gas turbine monitoring; and distillation tray efficiency calculation.

Multivariable model predictive or APC strategies are a central component of any refinery-wide optimisation programme. The benefits of implementing such a strategy are many: from improving process stability to reducing product quality variability to improving energy efficiency.

But perhaps, most importantly, it can allow a plant to operate even closer to product specification and process or equipment limits.

Part of the initial phase of either installing a new APC solution or upgrading an existing system is the deployment of advanced diagnostic methods to document control system performance. Through using these tools, it is easier to identify areas for improvement and establish the necessary actions.

Process control performance analysis tools and diagnostic service provide a comprehensive approach that includes information on process constraints, field actuator problems, loop interaction and model identification for improved tuning.

Building from the tighter operational control allowed by APC, a refinery is often able to improve its energy efficiency, product yields and throughput.

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S07 ORME 5 2013 Petrochemicals Feature_Layout 1 21/08/2013 16:59 Page 29

Petrochemicals & Refining

S07 ORME 5 2013 Petrochemicals Feature_Layout 1 21/08/2013 16:59 Page 30

However, APC alone is not sufficient in responding to changing market conditions.

Leveraging first principle process models alongside economic data enables real-time optimisation programmes to meet changing economic and market conditions. It is up to each refinery to determine the objective of a programme – such as maximising profit from optimal product slate or minimising costs at the production rate.

The combination of APC and real-time optimisation can realise benefits in the US$0.5-2.5mn and greater range.

Today’s refineries have new pressures stemming from business, energy and environmental concerns.

Properly managing energy costs for a refinery are now, more than ever, a deciding factor in determining a plant’s profitability. Refinery-wide optimisation solutions enable better oversight of all utility processes from the steam and power system to the hydrogen supply and demand.

Today’s business constraints prioritise the use of utility process modelling to make more informed and profitable decisions with new issues like the rapid management of steam and power generation and importation and distribution now factoring into an optimisation programme.

Rigorous CO2 emissions monitoring is also increasingly important for refineries to take into account, managed boiler modelling and electricity

30 Oil Review Middle East Issue Five 2013

import concerns. In what can be described as a delicate balancing act, the costs of external electricity need to be compared with the internal costs of generation and the overall environmental and regulatory costs of CO2 emission.

There are many benefits to be derived from better integrating planning and operational departments when analysing linear planning (LP) models. While these groups of staff often operate in relative isolation from each other, the decisions taken on which crude oils to process and how to operate a refiner’s process unit to meet end-product demands are better made through close co-ordination.

A refinery-wide performance optimisation solution helps bring together these functions, supporting planning departments in making more informed decisions and driving better performance.

These solutions will continually track the performance and changes in the refinery over time, adapting as it goes. As the optimisation model retunes itself in response to changing process conditions, it maintains the most accurate relationships across the process units and helps planning departments prepare for the future.

To ensure an optimisation solution fully reaches its potential, it must enable and automate a business impact ‘feedback loop’ for stakeholders. The enterprise manufacturing intelligence feedback loop in the solution acquires critical process and optimal

performance data from the optimiser and aggregates it with data from other refinery data sources.

This allows for staff to track, report and explain on the benefits of solution throughout the organization – demonstrating the importance of investing in further solutions. For example, Invensys has worked with one leading international company which reported US$1000 in benefits from optimisation for every US$25 it spends on maintenance and support of its optimisers. With such clear benefits, it is easy to justify investment in optimisation solutions.

Conclusion A holistic approach to refinery management enables a closer coordination and understanding between the operational and commercial sides of the plant.

As new demands from financial, regulatory and environmental perspectives are added, solutions which illuminate the opportunity for greater efficiencies are more sought after than ever.

With solutions like Invensys’ Refinery-Wide Performance Solution the payback on a properly structured and implemented solution can often be well under a year. The key themes of measurement, empowerment, control and optimisation showcase the broad range of benefits such a solution can bring a refinery – leading to better informed and profitable decisions. ■

www.oilreview.me

S08 ORME 5 2013 Petrochemicals A-B_Layout 1 21/08/2013 17:01 Page 31

RELIABILITY IN OIL WELL CEMENTS Oil Well Cement (OWC) produced by Oman Cement Company (S.A.O.G) under accurate temperatures is an obvious choice for oil well cementing worldwide and now it is ready to face the challenges of highly specialized arctic and horizontal cementing: ● Conforms to the American Petroleum Institute (API) specification – 10A Class-G- (HSR), Class-B- (HSR) and Class-A- (O) grades. ● Tested and used by worldwide cementing companies ● Easy to disperse resulting in considerable cost savings ● First choice of major oilfield companies ● Exported to GC Countries, Iraq, Yemen, Libya, Sudan, Tanzania, Turkmenistan, Ethiopia, Pakistan, India and Syria.

Oman Cement manufacturing facility operates on world class quality management system ISO 9001 and environmental management system ISO 14001. Quality control is online and laboratory automation systems consist of online x-ray spectrometers and robotic samplers, linked to process controllers and a raw mill proportioning system.

OCC has an enduring commitment to customer satisfaction, continual improvement and a stronger foundation for tomorrow.

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Petrochemicals

S08 ORME 5 2013 Petrochemicals A-B_Layout 1 21/08/2013 17:01 Page 32

Graham Corporation awarded Middle East contracts GRAHAM CORPORATION, A global company which engineers, manufactures and sells critical equipment for the oil refining, petrochemical and power industries, has announced that it was awarded five orders totalling US$10mn during July 2013, including two in the Middle East.

The projects are expected to ship at various times over the next nine to 15 months, from Q1 through to Q3 of the fiscal year ending 31 March 2015.

Two of the orders were for new ejector systems in the Middle East, with one for an oil refinery and the other for a new petrochemical production plant.

The contracts represent the company’s third win for the new 400,000 barrels per day (bpd) refineries being built in the region.

James Lines, president and CEO of Graham Corporation said, “We believe that the benefit of our diverse geographic and end markets is validated by these orders that represent the oil refining, petrochemical, edible oil and nuclear power generation markets. We further believe the reliability of our products and responsive customer service drove the three significant orders for replacement equipment and having a large installed base supports future aftermarket revenue opportunity.”

Lines added, “We believe that our order pattern confirms an improvement in our markets for large new and replacement equipment projects, as well as short cycle projects. While we are encouraged with this progress, we continue to expect our order rate will vary from quarter to quarter in these early stages of recovery.”

Egypt's petrochemical industry ‘witnessing strong growth’ EGYPT’S PETROCHEMICAL INDUSTRY is currently witnessing a tenfold increase, according to a newly-released report from research firm Research and Markets.

According to the study, the four petrochemical projects in progress throughout the country are expected to produce 2.6bn tons of petrochemicals over the next five years.

The ongoing projects are part of the Egyptian government’s 20year master plan to produce

petrochemicals for export, in addition to covering the demands of the local market.

The US$10bn three-phase master plan, launched by state-owned Egyptian General Petroleum Corp (EGPC) in 2002, predicts that more than 20 greenfield facilities will be in operation by 2022.

This will include 50 production units with a total capacity of around 15mn tons per year of intermediates and final products, alongside olefins and polyolefins complexes and plants producing

aromatics and methanol, EGPC said.

A methanol-to-olefins facility with downstream polyolefins facilities is also part of Egypt’s vision.

The Egyptian Petrochemicals Holding Co (Echem) is executing the programme, which is to be spread across seven sites in the north of the country and to cover approximately 30mn square metres, creating an estimated 100,000 direct and indirect jobs, the report said.

Iran petrochemical exports experience 46 per cent growth IRAN HAS WITNESSED a 46 per cent increase in exports of various petrochemical products in the past calendar year compared to the previous year, according to the deputy head of Iran’s Trade Development Organization, Kioumars Fatollah Kermanshahi.

Fatollah Kermanshahi, who made the announcement when speaking to Iran’s Islamic Republic News Agency (IRNA), said that exports of Iran’s petrochemical products had increased despite international pressures and sanctions imposed on the country in 2012.

Fatollah Kermanshahi also claimed that Iran had exported various tar products to more than 50 countries.

The Shazand Petrochemical Co. complex, Iran

Badger Licensing to provide cumene technology for Rabigh Phase II BADGER LICENSING HAS announced that it has been awarded a contract by Aramco Services Company and Sumitomo Chemical to provide its proprietary technology for a 384,000 metric tonne per annum cumene plant as part of the Rabigh Phase II Project in Saudi Arabia.

The contract includes technology license, engineering, training and start-up services for the cumene plant, due to start operations in 2016.

Mark Healey, president of Badger Licensing, said, “Rabigh Phase II is an impressive project in the growing petrochemical industry in the Middle East and Badger is proud to be associated with it.

“I believe Badger’s proven cumene technology will enable the Rabigh Phase II Project to achieve a low cost of ownership by leveraging long catalyst cycles and high operational reliability,” he added.

Cumene is a precursor to the production of phenol and subsequently bisphenol A and polycarbonate.

According to Badger Licensing, almost ten million metric tonnes per annum of cumene capacity has been licensed by the company and its predecessor companies since the technology was introduced in 1995.

Based in Boston, USA, Badger Licensing is principally engaged in marketing, licensing and developing technologies for ethylbenzene, styrene monomer, cumene and bisphenol A.

800-AGGREKO 800-2447356

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For all global locations, please go to: www.aggreko.com/contact

32 Oil Review Middle East Issue Five 2013

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S08 ORME 5 2013 Petrochemicals A-B_Layout 1 21/08/2013 17:01 Page 33

Petrochemicals

S08 ORME 5 2013 Petrochemicals A-B_Layout 1 21/08/2013 17:01 Page 34

APC/SATORP contract to boost polypropylene revenues

APC and SATORP signed an agreement to increase supply of propylene by 30,000 tons per year

ADVANCED PETROCHEMICAL COMPANY (APC) has recently signed an agreement with Saudi Aramco Total Refining and Petrochemicals (SATORP) to increase the supply of propylene in Saudi Arabia by 30,000 tons per year.

This brings the total supply from SATORP to 80,000 tons per year.

Last year, a short-term sales agreement was signed between the two companies for the supply of 50,000 tons per year of propylene.

The duration for the supply of the 80,000 tons has been amended from three years to five years, with the supply set to start from 1 January 2014.

The supply will contribute to an increase in production of polypropylene and thus a boost in revenues from the sale of the additional polypropylene, APC said.

34 Oil Review Middle East Issue Five 2013

Rolta wins Sadara engineering contract ROLTA INDIA HAS been awarded a contract from Sadara Chemical Company to implement a comprehensive engineering system at its Saudi Arabian complex.

The contract, the value of which has not yet been disclosed, will be managed by a global Rolta team working from India, the USA and Saudi Arabia, and will be completed by late 2014, Rolta said.

Sadara is a company formed of an alliance between Saudi Aramco and science and technology firm Dow Chemical Company.

With a total investment of approximately US$20bn, Sadara is now in the process of building an integrated chemical complex in Jubail Industrial City II. Taher Nemer, project manager of manufacturing and engineering systems at Sadara said, “A successful implementation of the engineering system is vital to the support and efficient operation of the Sadara Complex. We have partnered with Rolta on this challenging project because they have the breadth of sophisticated engineering IT expertise and have proven global delivery capabilities that are required for such an important project.”

Comprised of 26 manufacturing units, the Sadara Complex will possess flexible cracking capabilities and will produce more than three million metric tonnes of high value-added chemical and performance plastics products, Rolta said.

Rolta said it will leverage its knowledge of engineering work processes, application systems and IT and systems solutions which will support process engineering, technical support, process automation and control, asset integrity, analytical lab and standards and document management.

K. K. Singh, chairman and managing director of Rolta said, “We are very glad to have been selected by Sadara to implement its engineering systems. Rolta is fully committed to the success of this important project. This win provides further validation of our strategy of uniquely combining engineering and IT capabilities for delivering high value solutions to win significant new and follow-on business.”

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S09 ORME 5 2013 Erbil_Layout 1 21/08/2013 18:10 Page 35

One success leads to another Oil Review Middle East, the region’s leading oil and gas publication, has been putting sellers in touch with buyers for almost two decades. The magazine makes sure that it strikes a balance between respected editorial and your advertising message, to maximise the return on investment for your business.

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S09 ORME 5 2013 Erbil_Layout 1 21/08/2013 17:13 Page 36

S09 ORME 5 2013 Erbil_Layout 1 21/08/2013 17:15 Page 37

This year’s major show in the Kurdistan Region of Iraq promises to be the biggest so far.

The world can’t get enough of the recovering nation’s oil and gas.

Erbil Oil & Gas

Wise investors see progress

in the north A

T A PROVEN 150bn barrels, Iraq’s total oil reserves are amongst the world’s largest according to BP (June 2013), with most known fields being effectively undeveloped so far. As of July, international prices remained bullish, and Iraq’s total year-on-year production was 11 per cent up on last year. The North’s Kirkuk fields, close to Erbil (also known as Arbil, Irbil) where the 3rd International Oil & Gas Exhibition takes place from 2-5 September, probably hold one-tenth or more of those reserves.

On top of this, the gas resource could reach a ‘probable’ 350-400 tcf (nearly 130 proved so far), most of this associated. Much of the north of Iraq’s (nonassociated) gas reserves are completely unexploited so far, mainly because of the difficulties in marketing this key fuel - now widely in short supply elsewhere in the

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With decades of manufacturing experience and endless pursuit of development, we are committed to producing quality products and offering leak-free solution to create your best value.

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Oil Review Middle East Issue Five 2013 37

Erbil Oil & Gas

S09 ORME 5 2013 Erbil_Layout 1 21/08/2013 17:13 Page 38

Gulf - due to lack of infrastructure.

Major repair As well as developing these known and likely resources, experts say all sections of the nation’s oil and gas infrastructure need major repair, upgrades and extensions. Cross-border crude pipelines reach Syria, Saudi Arabia and Turkey.

Internal refineries feeding under-supplied domestic demand have a total capacity of just 0.6mn bbl; not only is the resulting supply inadequate (by about one-quarter), but the balance of saleable products, still oriented to HFO, is wrong, too.

Relations between North and South have not always been optimal, but the organisers of this year’s Erbil show* confidently say, “It seems there will be a new page for North Iraq’s future... The bottom line is that the region and the country as a whole need significant investments to catch up with the growing oil and gas demand. Both governments do not have the necessary financial strength, therefore they need the private sector involvement. And the private sector needs them to access huge reserves.”

raised amongst some potential international visitors as a result of organising events like this anywhere in Iraq, but this year’s exhibition team point out that this remains the most secure city anywhere in the country, with its own international airport offering direct flights to countries such as Austria, Germany, the Netherlands, Sweden and Turkey, as well as to several regional cities within MENA. Recently, national Oil Minister Abdel-Kareem alLuaibi revealed that the state is to invest US$130bn over five years in upstream development alone, in order to boost output to nine million barrels per day of crude. The gas industry is to receive a further US$18bn, with downstream refiners receiving US$25bn on top to reduce the product gap.

Last year’s Erbil International Exhibition attracted 5,000 visitors to see the products and services offered by more than 50 individual exhibitors, all keen for a slice of what is clearly going to be a very large cake indeed. BP itself said in June this year that, despite the American ‘shale revolution’ and a slowdown in the global growth of energy consumption overall, “oil prices reached another record high” (average for 2012, that is).

Concerns So this is what this year’s Erbil International Exhibition - now firmly established as an annual event - will be all about. Concerns are still being

Immense business They noted that worldwide oil trade grew by 1.3 per cent last year. So say the authorities in Iraq in

response to all this positive news for producers, shippers, traders and their agents: ‘Kindly join us in the third Erbil Oil and Gas Exhibition in order to take advantage of the immense business opportunities the Kurdistan region offers.’

Exhibitors this year will represent the following international industry sectors: 6 Construction of all types 6 Drilling and well servicing 6 E&P 6 Fuel retail and distribution services 6 General oil/gasfield equipment and services 6 Geophysical and geological services 6 Human resources development including recruitment, training 6 Laboratory equipment 6 Measurement and automation technology 6 On-/offshore applications of technology 6 Processing, refining including petrochemicals and LNG technologies 6 Security services and equipment 6 Software 6 Tools and electrical-power equipment 6 Transportation and pipelines ■

*Pyramids International, Expotim International and the local branch of M&T Solutions. For details visit www.erbiloilgas.com, e-mail info@erbiloilgas.com or call +90 (212) 356 0056 (fax 356 0096)

www.mcb.ae

38 Oil Review Middle East Issue Five 2013

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S09 ORME 5 2013 Erbil_Layout 1 21/08/2013 17:13 Page 39

the solution News

Total buys major stake in Kurdistan Region of Iraq

We create

TOTAL HAS ANNOUNCED that it has acquired an 80 per cent stake in an oil exploration block in the Kurdistan Region of Iraq.

The remaining 20 per cent of the Baranan Block will be owned by the Kurdistan Regional Government.

Total said in a statement, “This participation in an operated exploration block was contemplated at the time Total made its move in Kurdistan Region of Iraq last summer.”

In June 2012, the French energy company announced the acquisition of a 35 per cent interest in Harir and Safen oil exploration blocks in Kurdistan Region of Iraq, In June 2012, the French energy company an area that oil majors announced the acquisition of a 35 per cent interest in Harir and Safen oil exploration blocks such as Total, ExxonMobil and Chevron view as providing lucrative production-sharing deals and better operating conditions than in the south region, according to Wall Street Journal.

Chevron authorities recently said the firm had completed a deal to acquire a new oil exploration block in Kurdistan Region of Iraq.

Unlike Total and ExxonMobil, Chevron doesn’t have stakes in central and southern Iraq, industry sources said.

Oryx Petroleum ‘to develop Demir Dagh license in Kurdistan Region of Iraq’ ORYX PETROLEUM HAS plans to explore and develop the Demir Dagh license in the Kurdistan Region of Iraq, targeting an initial production of 7,000 bpd to 9,000 bpd in Q2 2014.

Oryx Petroleum, operator of the license with a 65 per cent participating and working interest, said its appraisal plan was awaiting approval by the Kurdistan Regional Government for resuming the Demir Dagh-2 discovery oil well and drilling three appraisal wells.

The three wells are expected to be produced from the Cretaceous, and at least one of them will retest the Jurassic and Triassic, company sources said.

The drilling would further establish the field structure and the extent of hydrocarbon fill and potentially result in larger reserves and resources to be booked.

Meanwhile, a preliminary lab results have confirmed field analysis conducted during the testing of Demir Dagh-2 that the crude oil in the Cretaceous has a low gas-oil ratio, low sulfur content and low viscosity.

Oil gravity is 23.1 degree, lighter than the 20-22 degree measured in field tests.

The company is likely to run extended well tests at the Demir Dagh-2 and the three appraisal wells to establish reservoir performance and pressure behavior.

The company’s Banan exploratory well is expected to spud in Q3 2013.

BAN-1 targets Lower Jurassic, Triassic light oil, Cretaceous and Upper Jurassic heavy oil.

BAN-1 is 8km from DD-2, and the two structures share a common spill point based on current interpretation of existing 2D seismic and observations of the Demir Dagh-2 well.

Results of the BAN-1 well could greatly affect Demir Dagh field development plans, according to company sources. www.oilreview.me

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Oil Review Middle East Issue Five 2013 39

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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

KOGT’s IT solutions for drilling KONGSBERG OIL & Gas Technologies (KOGT) has teamed up with Dynamic Graphics to provide oil and gas operators with significant enhancements to their key workflows. KOGT will offer a range of information technology solutions for drilling operations focused on getting the right data to the right people at the right time, to make critical efficiency and safety based decisions.

Full details can be found at www.oilreview.me

Aramco approves Fine Tubes’ products ARAMCO OVERSEAS COMPANY has approved Fine Tubes’ nickel alloy, stainless steel and titanium tubing. This approval recognises the quality standards, exceptional service levels and solid delivery performance Fine Tubes provides.

Full details can be found at www.oilreview.me

On achieving supplier approval from AOC, Fine Tubes successfully completed tube manufacturing plant evaluation

40 Oil Review Middle East Issue Five 2013

Chain stopper monitoring system SUBSEA VISION SYSTEMS manufacturer Bowtech Products has announced that it has delivered a chain stopper monitoring system to SBM Offshore, to monitor the chain stoppers during installation of the BP Quad 204 Turret Mooring System (TMS).

The system will allow visual monitoring of each chain stopper ratchet during installation phase.

Full details can be found at www.oilreview.me

The system allows visual monitoring of chain stopper ratchet during the installation phase

www.oilreview.me

S10 ORME 5 2013 Innovations_Layout 1 21/08/2013 17:18 Page 41

Innovations

S10 ORME 5 2013 Innovations_Layout 1 21/08/2013 17:18 Page 42

ThreatScan system monitors pipelines in real time to detect signs of external impact which could damage the pipe

ThreatScan guarantees accurate and real time data THE GE THREATSCAN system has proved to be immensely useful to customers in the oil and gas sector seeking efficiency and monetary gains.

By placing the ThreatScan sensors on oil and gas pipelines, GE collects, harvests, collates and analyses vast quantities of data that can prevent unnecessary downtime and promote more proficient ways of working.

The ThreatScan system monitors pipelines in real time to detect signs of external impact which could damage the pipe. Any impact on the pipe wall generates an acoustic noise which spreads inside the pipeline.

Acoustic sensors installed along the pipeline detect these changes and alert a GE monitoring centre. Correlations between two or more sensors are then performed at the GE monitoring centre to confirm and localise where the impact has occurred.

An impact notification message is sent directly to the customer who can then take appropriate actions to mitigate the risk.

Fluxys, a natural gas infrastructure company, has tested various impact monitoring systems and certified the ThreatScan system at the end of 2011 through a European joint research project.

In 2012, they installed 39 sensors to cover two 160km each pipelines linking the Netherlands border to the French border.

The ThreatScan system has been fullyoperational since January 2013, and permanently monitors these two pipelines against possible third party damage.

As Fluxys’ use of the ThreatScan system demonstrates, the industrial internet that sees the synthesis of big data analytics with GE’s expertise as an equipment manufacturer has great potential to help customers become more efficient, and promote safety.

42 Oil Review Middle East Issue Five 2013

Chukar to participate in Offshore Europe CHUKAR WATERJET, MANUFACTURER of ultrahigh pressure waterjet technology for deepwater subsea environment, will exhibit at Offshore Europe from 3-6 September in Aberdeen, UK. The company stall, stand 6B27, will showcase the latest technology that it has to offer to its customers. Chukar Waterjet offers ultra-high pressure (UHP) waterjet equipment capable of operating in the deepwater subsea environment.

Operable at depths up to 3000 meters, the company’s deepwater subsea waterjet system has numerous applications for deepwater emergency response operations, salvage operations, and rapid demobilisation operations.

It can cut steel up to 250mm thick and blast away concrete weight coatings, corrosion and marine growth at pressures up to 3,800 bar.

Waterjetting equipment also may be used to provide turbulence in a stream of methanol for hydrate remediation, an application Chukar developed in emergency response to the Gulf oil spill.

The company’s subsea waterjet technology improves the safety and effectiveness of subsea operations, allowing operators to access new types of work and larger projects.

Unlike conventional tools, waterjet cuts without heat, reducing the hazard of igniting trapped pockets of gas during cutting.

Waterjet system tools cannot bind in the cut, jeopardizing asset integrity. Chukar’s subsea waterjet system can be operated by a diver or ROV, and its remote-controlled operational capabilities make it suitable for projects requiring diverless operations.

Clock Spring’s composite casing spacers CLOCK SPRING FULLY-BONDED composite system has made a mark in casing spacer applications that prevent damage to pipelines and coating when installed (pushed/pulled) into the casing.

Traditional casing spacers tend to provide a segmented tooth profile and as such point loading and contact to the carrier pipe.

This often results in the spacer being broken or coming loose during the pipe installation process.

Derived from the transmission pipeline corrosion repair system, the Clock Spring casing spacer features the same full cured eight layer high-strength composite laminate coil which is wound onto the pipe Traditional casing spacers tend to provide a segmented tooth profile and bonded in place using a high lap shear strength adhesive.

Once installed the coil typically provides a half inch (12.5mm) stand off spacing distance from the pipe circumference, however, additional layers can be applied if a greater stand off distance is required.

The Clock Spring system is available to suit pipe diameters as standard from four inches to 56 inches with coil widths being available of up to 12 inches.

Sonardyne’s AMT delivers performance amidst challenges SONARDYNE INTERNATIONAL’S LONG endurance wireless sensor network has been able to log almost 90mn sensor readings as part of a major life of field system for three years continuously.

The company’s Autonomous Monitoring Transponders (AMTs) log nine measurements every three hours from a range of sensors built into each unit including pressure, temperature, roll and pitch even in depths of 1,200 metres.

In addition, each logging event consists of measuring highly repeatable ranges to every other AMT up to four kilometres apart and recording local and remote sound velocities.

The monitoring system is halfway through its planned six-year operation to meet an oil major’s research and production monitoring requirements. It has been continuously deployed since 2010, following an initial three year prototype trials phase, to assess the performance of the new technology.

Over the course of 24 hours, approximately 400 data records are collected resulting in

four kilobytes of accumulated binary data from each transponder on the sea floor.

This adds up to a total of 29mn measurements per year producing two gigabytes of data for analysis.

The time-stamped data logged within each AMT is available for recovery at the surface via the integrated high-speed acoustic telemetry modem.

Every six months, a vessel of opportunity is tasked with wirelessly recovering the data using a Sonardyne modem transceiver deployed through the hull of the vessel.

At each AMT location it takes approximately 10 minutes to upload the data at 15kbits/second to the vessel, from where it is immediately sent to a client FTP site while the vessel continues to move around the site.

Sonardyne engineering director Simon Partridge said, “This project gave us a chance to showcase our customer engineering services where we designed and manufactured this AMT version to fulfil specific requirements.” www.oilreview.me

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Innovations

Consistent performance quality has made FG Wilson a reliable player in the Saudi Arabian power generation sector

FG Wilson generators power Shaybah

oil field project F

UEL-EFFICIENT DIESEL and gas generator sets manufacturer FG Wilson has made a mark in the Saudi Arabian power sector with its reliable services and consistent performance.

Working in a project at the Shaybah oil field, scheduled for completion in 2016, with the government-owned Saudi Arabian Oil Company, Saudi Aramco, FG Wilson’s dealer in the Kingdom, Tamgo has been able to successfully deliver and set up power generation solutions required at the site.

As part of the Shaybah oil field project, worth US$2.76bn, Saudi Aramco required additional power to enable an increase in oil production to one million barrels a day and a five to six per cent increase in gas extraction every year.

To achieve such a production level, the company required a large-scale installation of generator sets on site. The project was tendered via Samsung Engineering, the main contractor for the project.

Tamgo won the project in May 2011, for the supply of 128 generator sets ranging from 13kVA–750kVA. The company supplied a large volume of FG Wilson generator sets, which were equipped to operate in extreme weather conditions, including temperatures of 55°C and severe dust storms.

The FG Wilson generator sets have been providing power to the compound for residences, offices and construction sites for the extraction of natural gas. Samsung Engineering has also delivered 11 gas-turbine generators and 44 compressors to help generate an additional 729MW of power at Shaybah project site.

Tamgo revealed that its technicians and engineers had to travel extensively, covering more than 1,200km, for the supply, delivery and commissioning of the 128 generator sets to the operating site. The company also said that it

FG Wilson and Tamgo have expertise in delivering quality services to large scale projects

conducted regular maintenance and servicing works with the generator sets operating in harsh climatic conditions. Saudi Aramco has also recently increased its order to 140 generator sets in total.

Tamgo added that the company’s commitment to support and maintain the installation of the generator sets, since the project began in 2011, has led to a long-term relationship with Saudi Aramco.

Though this project is due to be completed in 2016, Tamgo believes that more projects with Saudi Aramco might be in the horizon.

Tamgo product manager Islam Fathy said, “We are pleased to say we have designed, delivered and

commissioned 140 generator sets on site at present, all without a hitch. We are delighted to have forged a long-term relationship with Samsung Engineering and Saudi Aramco which we hope will continue to flourish even in the future.”

Shaybah NGL Recovery & Utilities Project cost engineer at Samsung Engineering Edward Jung said, “Saudi Aramco had a large project and needed a company that was capable to install a quality, costeffective solution in complex weather conditions.

FG Wilson and Tamgo have proven expertise in delivering large scale projects with success so we had no doubt they would be the perfect partners to deliver this project seamlessly.” n

Tamgo supplied and installed 128 generator sets at the project site equipped to function efficiently even in harsh weather conditions like extreme temperatures and dust storms

44 Oil Review Middle East Issue Five 2013

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S11 ORME 5 2013 Innovations D-E_Layout 1 21/08/2013 17:28 Page 45

Innovations

S11 ORME 5 2013 Innovations D-E_Layout 1 21/08/2013 17:28 Page 46

Scott Safety introduces Protégé ZM single gas monitor SCOTT SAFETY HAS announced the introduction of the Protégé ZM single gas monitor, which functions as a zero maintenance single gas monitor, which is easy to use and delivers high performance in a small, ergonomically designed package.

The Protégé ZM is a zero maintenance solution, meaning no battery charging and no sensor calibration is necessary to operate the monitor. The monitor has a high performance battery which provides two years of operation.

In typical conditions, calibration will not be necessary during the operational lifetime. Three single gas models are available including oxygen, carbon monoxide and hydrogen sulphide.

The Protégé ZM is small, lightweight, ergonomically designed and meets IP67 requirements for ingress protection.

Scott Safety’s global product line manager for portable gas detection, Mel Gerst said, “We

Protégé ZM is a zero maintenance solution with no battery charging and no sensor calibration necessary to operate the monitor

designed this monitor with ease of use and comfort in mind. The unique Protégé profile fits your hand nicely making the monitor comfortable to hold. It’s so lightweight and small. You will

forget you’re wearing it while it protects you.

“The monitor is very simple to use. Just turn it on for the first time, and it does the rest. Using the default settings from the factory there is no need to set up or program the monitor.”

The Protégé ZM features plenty of customisable settings to meet your specific needs. For example, a Hibernate mode is available on the CO and H2S models. The Hibernate mode puts the monitor in a deep sleep mode for up to one year to extend the operating life beyond two years.

Users can customise the alarm set points themselves or order monitors with custom alarm set points programmed by the factory.

Users can also set up custom bump and calibration reminders if they desire. The monitor has the option to display continuous gas readings, life remaining or both.

The monitor has a three point alarm (audible, visual, and tactile)

and data logging capabilities.

The Protégé ZM monitor is supported by a portfolio of accessories including a four-bay test station and IR Connect programmer. The test station supports bumping, calibrating, hibernating and programming of up to four monitors simultaneously, and is available in both portable and table-top versions. The IR Connect allows programming and hibernating of individual monitors.

Gerst explained, “The Protégé ZM Single Gas Monitor adds to Scott Safety’s 80-year legacy of working with customers to bring innovative solutions to market.

Our customers asked us for an easy to use single gas monitor that enabled them to focus on the task at hand instead of maintaining equipment. We are excited to expand the Protégé family of gas detection instruments with the introduction of the Protégé ZM.”

GE’s subsea signal detector creates ripples GE’S MEASUREMENT AND control subsea condition monitoring system, also known as the Cage, has made a mark in the oil and gas subsea sector.

Cage is equipped to measure sound and electrical signals emitted from subsea equipment, often an early warning sign of developing leaks and other issues.

The listening ‘ear’, which is an array of sensors in a 500-pound birdcage dome that sits on the sea floor or on subsea equipment, was developed at the GE Measurement and Control site in Bergen, Norway. A 210 metre deep water facility at the Bergen site also provided deep water testing for the technology.

Engineers designed the eardrum of the system

from special crystals that respond to sound wave vibrations and convert them into electricity. A single device can listen to sounds within a 1,600ft radius.

In addition, an array of attached carbon rods can detect changes in the magnetic field generated by electrical cables, pumps, motors and other electrical equipment in a subsea environment, and spot ground faults or defective isolation.

The device sends this sound information to a seaborne control room where the data is analysed to help plan maintenance and component replacement programmes.

GE measurement and control sales manager

Fabian Dawson said, “An acoustic signature from a piece of equipment is like a fingerprint from a human. No two leaks or pumps are going to sound the same. We can filter out the background noise, like marine life, and listen only to things we want.

“You can determine the revolutions per minute of a compressor from the acoustic signal and then you can determine how hard it is working from the electrical signal.”

Another benefit is that the sensors are located at a distance and are detached from the monitored equipment so do not interfere with on-going operations or processes.

Eaton to supply Sadara with electrical equipment EATON HAS ENTERED into an agreement with Sadara Chemical Company (Sadara) as part of which Eaton will supply motor control, power distribution solutions and engineering services to the chemical company.

Eaton will provide equipment and services to enhance the overall reliability and safety of Sadara’s world scale, fullyintegrated chemical complex, which is currently under construction in Jubail Industrial

City, Saudi Arabia.

The Sadara complex will produce more than three million metric tonnes of value-added chemicals and plastics to serve the rapidly expanding energy, transportation, infrastructure and consumer products sectors.

Eaton electrical sector Europe, Middle East and Africa region president Frank Campbell said, “Sadara will expand production of important chemical products and advance industrialisation,

46 Oil Review Middle East Issue Five 2013

job creation and innovation.”

With more than a century of power system design experience and a comprehensive global network of engineering and manufacturing resources, Eaton is well-positioned to help enhance electrical safety and reliability at this critical facility.

Eaton Electrical Sector will mainly provide custom electrical solutions to promote safe and reliable power distribution at the complex. Additionally, Eaton

Eaton will provide equipment and services to enhance the reliability and safety of Sadara chemical complex

electrical service and systems division, which has one of the largest and most experienced teams of power system engineers in the industry, will provide Sadara with electrical system startup assistance and training.

www.oilreview.me

S11 ORME 5 2013 Innovations D-E_Layout 1 21/08/2013 17:28 Page 47

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Innovations

S11 ORME 5 2013 Innovations D-E_Layout 1 21/08/2013 17:28 Page 48

Hi-Force takes delivery of logistics centre and training school UK-BASED MANUFACTURER of high pressure hydraulic tools Hi-Force has recently taken the delivery of a multi-million pound purpose-built facility, at the rear of the existing UK manufacturing plant. The new facility comprises almost 20,000 sq ft of built up area, plus an additional 15,000 sq ft of secure yard area, houses the complete UK logistical operation from raw materials through to finished product, plus a 1,500 sq ft ECITB approved training school. The new building is self-sufficient in terms of electricity requirements, thanks to its integral solar panelling within the roof area. Any unused electricity generated by the solar panels is pushed back into the national grid.

UK logistics manager Dave Summerfield said, “Moving of raw materials, components and finished goods, worth more than US$7mn, to a new facility, whilst still satisfying our global customers product and spare parts needs has not been an easy task. Thankfully the new facility has more than quadrupled the available space.”

Alongside the relocation activities, business development manager Pat Wright and training manager Steve Wakelin have been busy equipping the new purpose-built training school, which comprises a classroom, product practical training and demonstration area and product service and repair facility.

Hi-Force has already been approved by the Engineering Construction Industry Training Board (ECITB) to carry out mechanical joint integrity training as per ECITB training standards MJI10, MJI18 and MJI19 and plans are already in place to expand the Hi-Force ECITB approved training courses to other product and application areas.

An aerial view of the Hi-Force manufacturing facilities and logistics center in Daventry, UK

Construction and equipping of the training school has cost more than US$300,000, which has ensured that everything necessary to deliver training of the highest quality, is exclusively available as part of the training school tooling and equipment.

Training manager Steve Wakelin said, “Having the new training school located in the logistics centre means that trainers and delegates can be entirely focussed on the training, without the distractions we previously faced in the earlier much smaller training room, which was located close by to the production area. We have already had tremendous interest in our new ECITB approved training programmes and of course our standard product sales, service and repair training courses will be even better in this much improved new facility.”

Timberland Pro® expands its brand presence FOUNDED IN 1999, Timberland PRO® is a leading competitor in the industrial footwear space, creating premium products for markets that have specific on-the-job requirements. Technology, innovation and consumer research are the driving forces behind the success of the brand, as the company aims to continuously improve footwear in all aspects - fit, comfort, durability and safety.

Timberland PRO maintains a “simple blueprint for success,” a way to continually offer superior value to consumers within product offerings, all the while providing peak performance through best-in-class technical innovation. Features found within many Timberland PRO® designs include: 6 Timberland PRO® exclusive Anti-Fatigue™ Technology, which absorbs shock with each step and returns energy back to the foot for all-day standing comfort.

6 Polyurethane outsoles with triangular shaped lugs for a mechanical grip, providing the ultimate in slip resistance and traction.

48 Oil Review Middle East Issue Five 2013

signed to help reduce foot fatigue, support the arch and cushion every step, helping workers meet the demands of the work site 24 hours a day, seven days a week.

6 Breathable, waterproof linings, which combat heat stress and wick moisture away from the foot, keeping the foot cool and dry, ideal for hot and humid climates.

6 Ergonomic safety toes built on a TiTAN® last for foot protection and superior fit.

6 Timberland PRO® exclusive Powerfit Comfort System™, which uses a combination of ergonomically designed elements at key zones of the foot to supply movement and provide critical support.

6 A 24/7 Comfort Suspension System de-

Timberland PRO recently expanded footwear offerings to the MENA region, providing inventory directly to both distributors and end users. Timberland PRO is also a priority footwear supplier to Alcoa, one of the world’s leading aluminum producers, which now includes the Ma'aden facility, under a unique Saudi Arabia/Alcoa partnership.

Hundreds of thousands of workers now have access to quality, industrial footwear options, to help support them throughout the day, no matter what the terrain or temperature at-hand.

For more information about Timberland PRO® offerings in the Middle East and direct sales opportunities, please contact: John Spotts, director of international development, John_Spotts@vfc.com .

www.oilreview.me

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S11 ORME 5 2013 Innovations D-E_Layout 1 21/08/2013 17:29 Page 51

For enhanced maintenance efficiency YOKOGAWA ELECTRIC CORPORATION announced the release of the new SENCOM platform product series for the digital measurement of pH and ORP. This will join an existing lineup of pH/ORP solutions that includes the FLXA21 two-wire* pH/ORP-transmitter. With the release of the SENCOM platform products, Yokogawa says it will bring pH and ORP measurement into the digital era.

The SENCOM platform initially consists of a SENCOM module, the FU20F pH/ORP SENCOM sensor, a SENCOM cable, and the SPS24 SENCOM PC software. The installation of a SENCOM module in an FLXA21 transmitter will give it the powerful digital signal processing capabilities required to work together with the new SENCOM sensors.

Like its predecessor, the FU20F pH/ORP SENCOM sensor is a general purpose sensor that is suitable for a wide range of applications. The FU20F can store digital data and be calibrated using the SPS24 SENCOM PC software and/or the FLXA21. With these SENCOM platform products, our customers will be able to reduce the amount of maintenance work that needs to be performed on-site, thereby improving efficiency and reducing costs.

Liquid analysers are used in the oil, petrochemical, iron and steel, electric power, and water supply and wastewater treatment industries to control the quality of raw materials and products, monitor reactions, and manage the wastewater treatment process. The properties of certain solutions may cause damage to or foul the sensors in these analysers and thus adversely affect measurement accuracy, so sensor calibration is required on a regular basis. However, conditions vary and it is not always safe or convenient to perform the calibration work on-site, which usually requires a converter to store data and the use of standard calibration solutions. There is a need to move this work to a safer location and also reduce measurement downtime.

SENCOM comes from the phrase “SENsors with COMmunication,” which emphasises the data storage capability of these sensors.

Yokogawa Electric Corporation and its subsidiary Yokogawa Europe B.V. (headquartered in the Netherlands), have jointly developed the SENCOM platform for their customers to increase maintenance efficiency and reduce cost of ownership.

Following the introduction of the FU20F, which is the first sensor to be offered based on the SENCOM platform, Yokogawa will expand the SENCOM series lineup by adding products that support four-wire liquid analysers and thereby widen the scope of measurement.

Masatoshi Nakahara, senior vice president of the Industrial Automation Platform Business Headquarters, said, “To improve quality and production efficiency at our customers’ plants, it is crucial not only to improve plant facilities but also to keep measuring instruments in optimal condition for long-term stable operation. The newly developed digital SENCOM sensor will help customers improve maintenance efficiency and reduce costs. As part of our VigilantPlant initiative, Yokogawa will continue to develop and offer solutions that help its customers achieve the ideal plant.”

The SENCOM platform products

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Oil Review Middle East Issue Five 2013 51

Innovations

S11 ORME 5 2013 Innovations D-E_Layout 1 21/08/2013 17:29 Page 52

TDW announces record STOPPLE® Train pipeline pressure intervention T.D. WILLIAMSON (TDW), a leading supplier of pipeline services and equipment, announced that it recently performed the highest ever STOPPLE® Train pipeline pressure intervention in company history in Australia.

An operating pipeline pressure of approximately 1480 psi (102 bar) was maintained throughout the operation, which made it possible to safely remove and replace a pipeline valve in a remote desert in North West Australia.

TDW says it was retained to use the STOPPLE Train intervention method for a number of reasons. The operator wanted to make certain that the affected section of the pipeline could be tapped, plugged and safely isolated without shutting it down, which would have resulted in a halt in production.

The STOPPLE Train method uses field-proven plugging technology to temporarily block sections of live pipelines. It is the only system of its kind that links two plugging heads to form a “train” that effectively provides double-block and bleed isolation.

With its double-block and bleed design, it is possible to insert two plugging heads

52 Oil Review Middle East Issue Five 2013

The STOPPLE Train method uses field-proven plugging technology

through a single fitting. This method is preferable because it allows a technician to install two barrier surfaces (including a bleed

port for pressure and product evacuation) between work (such as welding or pipe cutting) being performed downstream and the line’s internal pressurised contents.

Prior to the operation, TDW custom-built a fully-rated 1480 psi (102 bar) STOPPLE Train system at its manufacturing plant in Tulsa, Oklahoma. Following a program of rigorous testing of the system to make certain that the job could be completed through the spool and fittings, TDW technicians travelled through the desert to the remote compressor station. Working in the early morning hours to avoid the 95°F (35°C) mid-day heat, the TDW team used a pressure-balanced tapping machine to hot tap the 16-inch pipeline, and the speciallyengineered STOPPLE Train system to plug it. For two days, the affected section of the pipeline was isolated while the valve was replaced and production flowed. The entire operation – including set-up, hot tapping, STOPPLE Train plugging, valve replacement, and setting the LOCK-ORING® completion plug – was completed in just seven days.

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S12 ORME 5 2013 Technology Focus Feature 01_Layout 1 21/08/2013 17:36 Page 53

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Technical Focus

Julian Cudmore, business development manager, Zenith Oilfield Technology, says the oil and gas industry today needs to monitor wells more closely.

New equipment simplifies

production

The Z-Sight system’s intuitive dashboard presents potential oil production gains

I

N TODAY’S DIGITAL world smart phones and portable tablet devices are the fastest growing and most widely used technologies in the world. Digital devices are now part of everyday life, where instant access to information has provided people a way to keep in touch and share information efficiently and economically. Information is now easily available at the touch of a button whenever and wherever one should require it.

In the artificial lift industry, it is still not uncommon for engineers to have to manually gather data, perform calculations and travel frequently to well sites to diagnose and troubleshoot problems. With ever increasing well populations being produced by artificial lift, operators are looking for safer, more efficient and cost effective methods of managing their fields.

SCADA systems in particular, have helped with

54 Oil Review Middle East Issue Five 2013

Secure log-in presents the operator with a field map of the wells the transportation of well data to the office, but as these wells have more sophisticated instrumentation installed, engineers can be faced with millions of data points a day to analyse. One method of coping with this volume of data is to employ exception reporting focussing only on resolving problematic situations through alarms and warnings; a purely reactive technique to managing data. Today’s industry requires proactive surveillance and automation to allow a shift from fire fighting troublesome wells, which ties up valuable resources, to efficiently applying expertise in order to optimise and increase production.

Proactive data management can turn complex data streams into useful information and, when automated intelligence is utilised, this information can ultimately be delivered as informed and valid recommendations.

Zenith Oilfield Technology, headquartered in Scotland, UK, has developed a multi-award-winning technology that transforms instrumented data into proactive surveillance, automated production optimisation and effective equipment protection.

The Z-Sight auto well surveillance system is a ground-breaking technology that provides the operator with the opportunity to automate the time consuming processes involved in managing and optimising a field of artificially lifted wells whilst reducing the HSE exposure of sending engineers to the well sites. The technology is helping operators around the globe increase production by between five and 50 per cent on average.

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S12 ORME 5 2013 Technology Focus Feature 01_Layout 1 21/08/2013 17:36 Page 55

Technical Focus

S12 ORME 5 2013 Technology Focus Feature 01_Layout 1 21/08/2013 17:36 Page 56

Operators are increasingly deploying artificial lift to enhance oil recovery. These wells need careful management to improve the ultimate recovery from reservoirs. Fields now contain hundreds of wells, each equipped with downhole pumps that require careful surveillance to minimise downtime, and detailed data analysis to ensure each and every well is producing to the optimum rate without sacrificing run life.

Operating conditions are becoming harsher as the quest for more oil takes artificial lift into new areas and pumps are being pushed to their limits.

Downhole sensors are now essential for effective reservoir management, lift system surveillance and protection.

The Zenith Z-Sight system gathers the instrumented data of each well and processes it with real time well models, this assists in validating missing or estimated well data. Once the process of validation is completed the automated well model can track the operation of the well in more detail than instrumented data alone can provide. The output of the system is delivered in a variety of formats from simple recommendations on how to best adjust the well’s operation, to detailed performance curves to assist in well diagnosis. The in-depth automated data validation and modelling processes used enable the system to deliver minute-by-minute virtual well test results, dynamically calculate the optimum values for alarm set points to protect the lift equipment, and perform real time sensitivity studies on the well data to predict potential production gains.

The desired production rate target is set by the operator and the Z-Sight system will calculate the optimum operating point required to achieve that rate. The target production rate can then be adjusted on the fly as the operator sees in real-time the response of the reservoir. This, along with onboard virtual water cut metering, allows the operator to adjust bottom hole flowing pressures in response to changing oil cuts over multiple wells being produced from the reservoir.

In a recent case study, an operator increased production by US$2.5mn on one well over 345 days by following the recommendations of the Z-Sight system. The well was previously thought to be running at its maximum potential.

In a second case study, oil production was more than doubled following implementation of the system’s suggestion to upsize the pump in order to achieve the desired bottom hole flowing pressure.

The additional revenue generated by this recommendation was US$55,000 per day in increased oil production.

In any optimisation process it is extremely important to recognise the limitation of the lift equipment providing the production. The system’s on-board calculations work within the boundaries of the specific equipment installed in its well, ensuring that any recommendations will always be within the capability of that equipment.

Automating the operation of the downhole pump actually extends the run life of the equipment as it is continually checked to be running inside its various operational envelopes. If well conditions

56 Oil Review Middle East Issue Five 2013

Z-Sight remote web interface showing recommendations

change, the system will recalculate the optimum operation to bring the lift back within its limits at the maximum available production rate obtainable.

The technology utilises parallel processing, a technique where each well has its own individual processor monitoring and diagnosing its assigned well in real time and in great detail. This technique enables the reactions of operational changes of one well to be seen immediately on neighbouring wells, or wells sharing the same flow lines. The system will send intelligent recommendations or automatically adjust nearby wells’ operation to compensate for any changes it sees from wells operating in the same network.

The Zenith Z-Sight system gathers the instrumented data of each well and processes it with real time well models For example, speed was increased on an ESP well to meet the bottomhole flowing pressure target. A consequence of the increased production on this well was increased back pressure in the flowline, which was used by many other wells to produce fluid to a gathering station. The resulting increase in back pressure on the flowline decreased the production from the wells feeding into the line.

The system recognised the change in operation of these wells in real-time and automatically suggested the necessary action to compensate for the changes well by well. The parallel processing power of the system enables this to be performed in real-time, ensuring each and every well is making its production target.

Case studies from around the world have shown this technology to be capable of working effectively on wells with high GOR, and wells with emulsion

and scaling problems, in addition to wells with multiple ESPs deployed and downhole smart completions producing from multiple zones.

The system essentially takes the hard work out of well surveillance by automating the process of data analysis and optimisation.

All data is displayed on simple to understand dials on a large touch screen showing real-time charts and well status report. Both field and office personnel can quickly see when the pump and well are operating correctly.

Remote access through a secure internet or internal company intranet connection facilitates surveillance and control of the lifting equipment from anywhere with a standard web browser. In areas where national production data is absolutely confidential, the complete system can be deployed within the operator’s network to ensure no data is transmitted outside of the country.

Secure log-in presents the operator with a field map of the wells, each with a status flag. The status flag indicates whether a well is not producing, has a pump or well problem that requires attention, has potential for optimisation with a recommendation on potential gains, or is running optimally and requires no further attention.

The operator can instantly recognise and prioritise wells requiring attention, make informed decisions and action those decisions quickly using the remote control function to start, stop or change operation of the well.

Through remote access and control, operators have complete command of their operations in an instant. They are immediately notified by email or SMS when a well shuts down and production is being lost. The operator then has the ability to resume production immediately through secure remote control of the pump drive.

Julian Cudmore, Zenith’s business development manager explained, “Wells are not always being monitored as closely as they should be, unless something critical happens to production such as pump failure or serious well problems.

“The Z-Sight system is an efficient field www.oilreview.me

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Technical Focus

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management tool which automatically processes information relating to the interaction between well and pump. It can recognise whether a performance problem is pump or well-related so appropriate action can be planned and implemented without delay.”

The game-changing technology has now been deployed in hundreds of wells around the globe, both as a standalone system to provide remote access to data or as an enhancement to an existing SCADA system to provide automated surveillance and optimisation benefits. It can be installed on both onshore and offshore environments and ESP and PCPproduced wells.

The company has recently secured full field development contracts in two continents where field trials successfully demonstrated the robustness and benefits of the system to the operators.

Greg Davie, Zenith’s general manager, said: “Zenith thrives on a hunger for advancing technologies to address industry challenges.

Our developments re-think common practices in well and field operation, delivering solutions

Automatically generated field reports enable efficient data management

such as Z-Sight auto well surveillance to turn the operator profit curve upward.”

Zenith Oilfield Technology, a Lufkin company, operates in the artificial lift sector of the global oil and gas industry. Specialists in well monitoring, the company designs, develops, assembles and supports pioneering

industry leading technologies to enable optimum recovery from customer wells through the gathering and analysis of downhole data. The team also specialises in the design of innovative well completion equipment to reduce operator downtime and intervention costs. ■

Region a key growth market for artificial lift OIL REVIEW SPOKE to vMonitor and Kuwait Oil Company (KOC) about the evolution of artificial lift technology and why the Middle East is a real growth area for the technology.

Sami Suheil, COO of vMonitor discussed how the Middle East provides a great upside for the artificial lift market and Ahmed head of business development Unit at Well Surveillance Group at KOC explained how artificial lifts are playing a crucial role in increasing Kuwait’s production levels.

Suheil stated, "Easy oil is behind us and more and more wells are being converted to artificial lifts." vMonitor sees a lot of opportunities in the artificial lift market, which globally is worth US$11bn and is growing between 15-18 per cent each year, according to Suheil.

The Middle East region is seen as a major growth regions region as fields are maturing and depletion of reservoirs starts to set in. "The need for artificial lifts in the Middle East is growing," he noted. vMonitor is focused on the artificial lift market in the Middle East region with Oman historically being the firm's biggest market but Kuwait is its fastest growing market.

"Oil fields in Kuwait are being converted into artificial lifts and the Kuwait market provides a great opportunity," Suheil noted.

Kuwait is putting a lot of attention on artificial lifts to help the country increase its overall production levels.

"KOC is looking at the big picture towards Kuwait's 2020 strategy, with a major component being increasing the country’s overall production levels to 4mn bpd. We are currently producing between 2.7mn and three million bpd," remarked Ahmed.

He added that in order to achieve this increase Kuwait will need to bring in a lot of new technologies that can help to increase our production levels, which is where artificial lifts comes into play.

Kuwait is focusing on using conventional artificial lift equipment but will also be looking at unconventional lift opportunities in the near future, according to Ahmed.

"We are increasing in number and types of artificial lift to help us face the challenges of meeting the 2020 goals," he added.

KOC are increasing rapidly the number of conventional artificial lifts they operate; including electrical submersible pumps (ESP), Gas Lifts and CPC. From 2005 to 2010 Kuwait increased the number of artificial lifts it uses

58 Oil Review Middle East Issue Five 2013

expediently. There are now almost 1,000 artificial lifts in operation.

"It is the future of production,” claimed Ahmed.

They are also piloting unconventional techniques for the extraction of heavy oil, including advanced types of ESP or steam injection.

In three to four years Kuwait will be ready to increase its heavy oil production. The aim would be to have 600 unconventional artificial lifts ready in four years time.

He commented, "Artificial lift for heavy oil is very challenging. We established a team to deal with steam injection and we are working on a number of pilot schemes and preparing for full implementation in a couple of years.

Of the various artificial lift technologies out there, Suheil argued that growth will follow electrical submersible pumps (ESP), progressive cavity pumps (PCP), jet pumping of the various pumping applications available.

"ESP will definitely be the most followed technology, followed by PCP. Simply because of the American petroleum Institute (API) of the crude in the region," he noted.

PCP and BCP can make a significant impact in Oman and Kuwait where the reserves are more heavy crude.

Gas lift technology will play a part but it will not see the same growth rates as other pumping systems. This is because of the associated hazards with gas, such as safety issues when running highly compressed gas along long distances.

The UAE is embarking on a major gas lift programme and vMonitor are involved and have a pilot up and running.

New technology plays a big part in the evolution of artificial lift techniques.

As Suheil said, “It is a very mature technology but it is evolving.” vMonitor have been pumping a lot of resources into R&D and they have run a few pilot tests on a couple of wells with their new multi phase virtual metering system, which has not entered into commercial perspective.

The pilot tests have run on four wells in Latin America and on two wells in the Middle East. The results have been very encouraging, according to Suheil.

The new product uses mathematical and analytical tools along with some basic measurements to give a multi-phase reading within two to seven per cent.

Suheil stated, “The industry is moving down the line of having fully integrated solutions and we are moving along with this.” www.oilreview.me

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Tendeka has developed a range of solutions around one central area of focus – the near-wellbore region. Wherever operators need to isolate zones, control individual technologies or a combination of systems for the challenge.

As a result Tendeka customers arrive at more effective ways to manage their reservoirs, enhance production and increase overall recovery.

Speak to us today about where Tendeka can take you.

See the whole picture at www.tendeka.com

Monitoring

Modeling

Completions

Control

Technical Focus

S13 ORME 5 2013 Technology Focus Feature_Layout 1 21/08/2013 17:48 Page 60

For tank storage firms, the risk of a lightning-induced fire event is potentially too damaging to bear, says *Roy Carpenter. ADNOC’s Takreer is one company that has taken steps to minimise the risk.

Takreer takes the low impedance path

to tank safety F

LOATING TANK STORAGE facilities that have millions of dollars’ worth of product can be destroyed with a single spark.

Even worse is the downtime such an event will cause: a possibly lengthy period of investigation and reconstruction that impacts a storage facility’s ability to deliver product to market and generate revenue.

Last year, Takreer, a storage and refinery subsidiary of the Abu Dhabi National Oil Company (ADNOC), completed a thorough lightning protection analysis and began transforming its protection profile for floating roof tank storage.

Dozens of tanks, while operating efficiently, had potentially faulty lightning protection systems in place: metal shunt and wire systems that are meant to direct charge in the case of a lightning event but are prone to fall into disrepair over time.

Progressive “Because Takreer is a very safety-conscious company, they called us and Lightning Eliminators & Consultants, Inc. (LEC) for a better lightning protection solution,” said Manoj Nambiar, general manager of Consilium Middle East Fire Protection and Safety operations.

“As a company that handles high volumes of storage, Takreer has to be very progressive about making sure their facilities are protected.”

Consilium Middle East (FZC), which sells and installs fire protection solutions to many of the major oil and natural gas companies throughout the region, started offering LEC’s Retractable Grounding Assembly (RGA™) lightning protection solution to companies that want the best levels of lightning protection available. Last year, Consilium and LEC services outfitted 84 tanks at Takreer’s Ruwais refinery with 450 RGA assemblies. And, the company is starting on a new contract to install RGAs on another eight Takreer storage tanks in Abu Dhabi.

While those installations are retrofits to existing tanks that have less-effective lightning protection systems, Takreer has also begun including RGAs in its specifications for new tank construction as well.

Takreer and other oil storage and refinery companies worldwide choose the RGA because floating roof tanks are notoriously difficult to protect from lightning.

Other floating roof tank grounding solutions often fail because they require a great deal of maintenance and upkeep: Metal shunts used for grounding on floating roof tanks regularly break, and wires used for the same purpose often tangle, compromising the low-impedance path they are

60 Oil Review Middle East Issue Five 2013

The product creates a permanent, reliable, lowimpedance bond that prevents fires triggered by lightning currents supposed to create for safe operation.

The patented, award-winning RGA replaces the frequently damaged metal shunts and wires. While RGAs require routine maintenance and inspection like any other piece of hardware, they are not easily compromised and require a fraction of the repair and replacement work seen with other systems.

Adequate protection Takreer’s stance with enhanced lightning protection using RGA solutions is especially progressive as the company operates in a part of the world that is not known for excessive lightning. While lightning activity in Abu Dhabi is in fact low, the company is now better protected from a global trend: incrementally higher lightning activity that scientists believe is the result of climate change. Higher temperatures worldwide are increasing the warm-weather patterns that lead to severe thunderstorm activity.

Even without the global increase in lightning, floating roof tanks need adequate protection. Large storage operations such as Takreer’s Ruwais facility, for instance, houses millions of dollars’ worth of product, which means a single, lightning-induced spark can result in a tremendous financial hit. It is a common and unfortunate challenge that storage firms face worldwide. In fact, some studies have indicated that a majority of fires that occur with petroleum storage tanks are caused by lightning.

Part of the difficultly is the fact that tanks are susceptible not only to direct lightning, but also to nearby strikes.

Very damaging “When lightning is about to strike nearby, electrons in the area nearby rush over to the point of a strike, and good grounding systems allow that to happen without incident,” explained Kirk Chynoweth, systems engineering manager for LEC. “Unfortunately, when the roof of a floating roof tank is not properly grounded, the electrons on the top of the tank will move at a different rate than electrons on the side of a tank, and that difference in charge balance can create a spark on the edge of the floating roof.”

Those sparks occur in just about the worst place possible, the empty space above a stored petroleum product that is full of flammable fumes.

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Technical Focus

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For that reason, tank fires are often very damaging.

A July, 2012, strike that happened at a US company in Kentucky is not all that unusual: it destroyed at least two tanks, set additional tanks on fire, and damaged on-site power lines, subsequently creating power outages in the surrounding areas. The floating roof from one of the tanks was blown off and landed in the middle of a nearby highway.

Fortunately for Takreer, those types of lightningrelated incidents are less and less likely because of its proactive lightning protection operations with Consilium and LEC. The reduced maintenance that the RGA requires compared to older lightning protection systems has led Consilum to begin conversations about lightning protection with some of Takreer’s sister companies in the energy sector.

“You can’t be too safe when you have as many assets to protect as Takreer does,” said Consilium’s Nambiar. “Takreer is a company that goes above and beyond even the most stringent guidelines for protection and, when it comes to lightning protection, they have made sure that they have the lowest-impedance path for grounding with their RGA systems.”

Highly economical The RGA, a winner of the E&P Innovation award, solves the challenges that come with traditional grounding devices, providing comprehensive

62 Oil Review Middle East Issue Five 2013

Lightning Eliminator’s Retractable Grounding Assembly RGA®

lightning strike protection for floating roof tanks.

The product creates a permanent, reliable, lowimpedance bond that prevents fires triggered by lightning currents.

The RGA is also a highly economical device, and it can be installed on new and existing tanks in approximately two hours.

The ATEX-certified patented RGA conforms to both API 545 and NFPA 780 recommendations and is supported by API 545 as a bypass conductor.

LEC is dedicated to providing integrated, industrial lightning protection and prevention solutions, products and services by utilising innovative, patented charge transfer technology,

grounding systems engineering, surge protection, design and comprehensive consulting resources.

To date, LEC has installed more than 3,000 solutions in more than 69 countries and throughout the United States, providing lightning protection to companies in the petrochemical, oil and gas, biochemical, information technology, nuclear energy, utilities and manufacturing industries. n

*Roy B. Carpenter, Jr., a former chief engineer for NASA’s Apollo Moon Landing Missions and the Space Shuttle design engineering teams, founded LEC in 1971 to study and apply engineering principles to lightning protection.

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For more than 30 years

In the UAE and the Middle East, Technip continues to contribute to the success and the development of several Oil and Gas complexes and projects in the region.

Whether onshore, offshore or subsea, Technip possesses the know-how, technologies, assets and man power, of 1850 employees in the Middle East, to deliver safely and successfully through constant customer focus and integrated and sustainable approach.

Contact us: +97126116100/6000 www.technip.com

Technical Focus

S13 ORME 5 2013 Technology Focus Feature_Layout 1 21/08/2013 17:48 Page 64

With Jason’s 3D Interpretation software interpreters can visualize subsurface data including wells, horizons, faults, seismic and rock property volumes (Image courtesy of Jason)

CGG offers Middle East a new broad spectrum of integrated geoscience services CGG IS OFFERING Middle East clients new integrated geological, geophysical and reservoir capabilities that will bring value to many aspects of natural resource exploration, development and production.

At a time when most future oil and gas production is likely to come from increasingly challenging prospects and improved recovery from existing reserves, there is growing emphasis on the value of an integrated geoscience approach to achieve the best possible understanding of the subsurface at all scales to increase exploration success, reduce risk, and maximize recovery.

One of the most significant changes for CGG since the closing of the Fugro Geoscience acquisition is the expansion of its products and services that will enhance natural resource finding, characterization and recovery across the full exploration and production value chain.

Leading reputation The company has long been a dominant leader in the seismic products and services arena, a very important element of the cycle, but less present in the arenas of field development and production management. With the addition of powerhouse brands Robertson and Jason and an increased portfolio covering methods such as geology, gravity, magnetics, near-surface geophysics, and airborne, CGG has gained new expertise in services that can help operators build a stronger, more comprehensive Earth model.

When combined with the company’s already

64 Oil Review Middle East Issue Five 2013

leading reputation in equipment through subsidiary Sercel, who also recently expanded its portfolio with downhole technology and permanent reservoir monitoring systems such as Optowave™ and SeisMovie™, and recent partnership initiatives such as its shale alliance with Baker Hughes and the joint venture, Seabed Geosolutions that CGG has just formed with Fugro, a clear trend has emerged for CGG. It has gradually been expanding its scope, by strategically leveraging its leadership position in seismic acquisition and imaging, to add value to its offer at each step in the exploration to production cycle.

Cost-effective “Our ability to combine high-end geophysical, geological and reservoir expertise to solve a client’s unique problem will be a key differentiator and will enable a more integrated approach to managing the E&P lifecycle. Leveraging our proficiency in geophysics in a manner that delivers improved subsurface clarity with faster results that can be quantitatively integrated within reservoir models will ultimately help our clients improve recovery in a more cost-effective manner,” said Sophie Zurquiyah, EVP of CGG’s Geology, Geophysics & Reservoir (GGR) division.

While the company will continue to focus on its core areas of expertise in 1) equipment, 2) acquisition and 3) subsurface imaging and reservoir characterization, it will seek opportunities to combine the knowledge of those three areas with its new capabilities in geology in ways that will

enhance its clients’ ability to yield greater returns on investment in shorter amounts of time.

Techniques In the Middle East region CGG sees a unique opportunity to develop science that could greatly improve the industry’s understanding of how best to exploit vital natural resources. With detailed reservoir models that incorporate geological, geophysical and petrophysical information, CGG believes it can dramatically improve development decision-making, and already these synergies can be seen today. As first business opportunities, CGG has submitted comprehensive integrated proposals to several Middle East and Arabian Gulf National Oil Companies for the exploration, appraisal and development of unconventional shale and source rock plays where there is great benefit in the integration of multi-disciplinary data into predictive reservoir models.

Petrophysical information is calibrated to surface seismic using a variety of seismic reservoir characterization techniques. These results are then validated with mineralogical analysis of cuttings and cores, and microseismic datasets giving insight into reservoir quality, rock strength and stress.

Production measurements can be correlated to seismic predictive volumes for high grading locations, and providing a guide for drilling and completion decisions. This is a powerful indicator of what the future potential could be and is exactly the kind of expertise CGG hopes to develop further in collaboration with Middle East clients.

www.oilreview.me

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Technical Focus

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3M ‘transforms’ grinding DIVERSIFIED TECHNOLOGY COMPANY 3M has introduced a range of bonded abrasive grinding wheels into the European market which it claims offer an innovative new approach to the grinding process. Employing the highly advanced abrasive grain technology, precision shaped grain, introduced with the Cubitron II Abrasive Belts and Discs from 3M, now well established in the market, the new grinding wheels cut faster, last longer and require significantly less pressure than conventional grinding wheels, according to a company statement. This apparently results in increased productivity and reduced operator fatigue.

Suitable for heavy weld removal as well as numerous other grinding applications, Cubitron II Bonded Abrasive Grinding Wheels are capable of delivering extremely high cut rates

on an extensive range of metals, making them ideal for fabrication, maintenance and repair within the oil and gas industry.

David Atherton, senior marketing executive for the 3M Abrasive Systems Division, explains: “This is

66 Oil Review Middle East Issue Five 2013

an innovative grinding technology that cuts faster and lasts longer – tests have shown that the new grinding wheels achieve significantly increased output when compared with conventional products. The introduction of Cubitron II Bonded

The new grinding wheels cut faster and longer, say 3M

Abrasive Grinding Wheels from 3M can have a major positive impact on the essential metalwork required for oil and gas applications.”

The irregularity of conventional ceramic grain results in it ‘ploughing’ through metal, causing a build-up of heat and resulting in a slower cutting rate; this directly affects product durability, potentially resulting in shorter life. In contrast, precision shaped grain technology features precisely-shaped, uniformly-sized and verticallyoriented triangles of ceramic abrasive. These self-sharpening structures fracture as they wear, forming new, super-sharp points and edges, which slice cleanly through metal, rather than gouging or ‘ploughing’, allowing the grinding wheel to stay cool and last longer.

This has the potential to deliver significant advantages in productivity and consistency, as well as longer service life.

www.oilreview.me

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Easing the burden of suspended well decommissioning OFFSHORE INSTALLATION SERVICES Ltd (OIS), an Acteon company, has launched a new service designed to help operators fulfill their suspended well decommissioning plans. Wellintel is a well data collection and review service that gathers and prepares the information operators require before they start a decommissioning program. OIS engineers with extensive well abandonment knowledge and detailed understanding of the entire decommissioning process will deliver the service.

Operators having an up-to-date well inventory and regulatory documentation ready for submission to DECC and the HSE can take advantage of commercially efficient opportunities such as multi-client abandonment campaigns that may arise at short notice.

Decommissioning offshore assets is a key challenge for the UK’s offshore oil and gas industry. The UK government’s Department of Energy and Climate Change (DECC) is prompting operators with assets that require permanent abandonment to expedite the process.

www.ois-ltd.com

For many operators, the main obstacles are lack of time or limited in-house resources to deal with the critical tasks required to prepare for decommissioning. The Wellintel team will help by collating well-specific data, such as end-of-well reports and well status diagrams, and the initial assessment of well categorization in accordance with O&G UK guidelines, which is required to identify which assets are available and suitable for vessel-based abandonment, thereby easing the burden on operators.

The Wellintel service can also support operators with preparing the submissions to DECC and the HSE that are required before starting a decommissioning program. These submissions include the oil pollution emergency plan, PON 5 (application to abandon a well), PON 15f (permit to use and/or discharge chemicals during well abandonment), the Marine Coastal Access Act licence and the HSE notification.

Since its launch, Wellintel has attracted a high degree of interest amongst North Sea operators who recognize the value of this approach. One operating company has already started using the service as part of its decommissioning strategy.

One of the key features of the proposition is that the costs of the Wellintel service are deductible from future abandonment work by OIS, as Tom Selwood, OIS vice president commercial and business development, explained. “Once the Wellintel process is complete, OIS can provide well abandonment solutions, including vessel charter, marine management, equipment and personnel, and full offshore project management for any suspended wells that are suitable for vessel-based abandonment. Operators that use OIS for back-of-boat suspended well abandonment work within 18 months of using Wellintel can recover the costs incurred against the project management fees associated with the well abandonment project.” www.oilreview.me

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Technical Focus

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There is no doubt that sand management and control is a major concern facing the oil industry today as it looks to maximise yield from ever more challenging resources. Sand infiltration has the ability to damage equipment, impact on performance and, in some cases, even stop production. Produced sand has the potential to cost the oil and gas industry billions of dollars annually and can pose a safety and environmental risk.

Options for

controlling sand C

ONTROLLING THE FLOW of unconsolidated sand into the well is one of the most critical challenges in any sand face completion. The failure to address sand production correctly will impact heavily on productivity, well life, completion equipment life and safety through eroding surface equipment, as well as the environmental and financial impact of disposing of large quantities of sand.

In unconsolidated formations, typically with a permeability of 0.5 to 8 darcies, high flow rates and drawdown pressures trigger sand production, as the drag from the formation fluid or gas turbulence detaches sand grains, carrying these unwanted products into the well.

Without adequate sand control, migration of reservoir sand and fine material into the wellbore or near-wellbore area may compromise the structure of the reservoir around the wellbore, particularly in weak formations, and can severely restrict production. Besides prematurely killing well production, excessive sand production causes erosion and the blockage of downhole hardware, seriously damaging or disabling downhole and surface equipment, and must be separated and disposed of at the surface.

Various methods Over the last few decades drilling technology has advanced to such an extent that horizontal and multilateral wells are now the norm, with greater reservoir penetration and lower draw-down pressures.

This increased length and uneven pressure profile along the wellbore has resulted in an increase in sand control issues, as any water influx can also cause sand production because of a reduction in the capillary pressure between sand grains.

Sand control is basically the control of sand production in unconsolidated formations, and the first step in any sand control application has to

be a detailed exploration of the characteristics of that formation. There are various methods used to determine the optimum sand control methods for each specific well and in many cases the decision can come down to a trade off between these various solutions to provide the best overall option for the client.

Establishing the formation sand grain size is essential to sand control selection and laboratory technology is utilised to help establish the most suitable sand control method.

Greater recognition Traditional completion methods, such as resin injection, gravel packing and stand-alone screens, which allow sand-prone reservoirs to be exploited, often dramatically reduce production efficiency and are being replaced by alternative technologies that extend production utilising Inflow Control Devices (ICD) in conjunction with sandscreens. Inflow control device (ICD) screens keep formation sand in place without unduly restricting productivity and are a relatively straightforward installation. They can be deployed to reduce or delay an influx of water, but have added sand control benefits in that they can reduce annular flow to near zero, thereby reducing the risk of erosion hot spots.

This type of completion solution has been most prominent and highly successful in the Middle East and the North Sea, but is gaining greater recognition elsewhere in the world.

Production from horizontal wells is never uniform from toe to heel, and without inflow

A key question in the drive for enhanced production is how best to control and manage sand

control greater drawdown at the heel of a well results in lower oil production and recovery. With high-permeabilities in the reservoir section allowing a high influx of water and gas, and poor or limited clean up of the mud from the toe section, production can be compromised.

ICDs are used to enhance the performance of horizontal wells in unfavourable environments such as non-uniform permeability and/or pressure along horizontal sections. The advent of inflow control technology has dramatically improved well productivity and wellbore cleanup, resulting in increased recovery and the associated benefits. An ICD is deployed as a part of a well’s completion to create an evenly distributed flow profile along a segmented producing zone.

Well performance Each ICD placed along the producing zone creates a localised restriction to flow that is pre-determined during the completion design. This restricted flow creates an additional pressure drop, balancing the wellbore pressure drop. The resultant evenly distributed flow profile can reduce water or gas coning, sand production and solve other drawdownrelated production problems.

Stand-alone ICDs can be spaced throughout the completion liner adjacent to the production or injection reservoir. They can be placed on every joint, or run in combination with blank joints to provide the desired well compartmentalisation and inflow profile as per client requirements.

A well-designed ICD completion, assisted by wellbore hydraulic modelling, can promote production from the entire horizontal laterals and mitigate the effect of the severe pressure gradients.

It can eliminate cross-flows existing in open hole completions and, in certain cases, ICD completions can significantly reduce water cut thus significantly improving well performance.

Tendeka FloRight product with FloCheck ICD valve, FloMax Ultra Screen and SwellRight slip on Packer

68 Oil Review Middle East Issue Five 2013

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Technical Focus

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ICD technology comes in a variety of modes, fixed, adjustable, and with shut off capabilities in conjunction with sliding sleeve technology.

In multi-phase flow, passive (or fixed) ICDs can reduce the effects of water and gas breakthrough when phases have higher mobility than the desired oil. By altering the nozzle size or quantity of nozzles, a pre-determined flow rate and pressure drop can be achieved.

Design simplicity In a conventional production well, the produced fluids have a tendency to cone to the heel of the well resulting in high annular fluid velocities, which can carry harmful fines increasing the possibility of screen erosion. This uneven flux can lead to early water or gas breakthrough, reducing the serviceable life of the well, and result in lost recovery and revenues. By installing ICDs, a predetermined pressure drop can be created between the reservoir and the completion liner. This results in a backpressure on higher quality sections of the reservoir, allowing tighter sections to contribute to evening out the inflow or outflow profile. This evening out of the inflow profile will result in better coning control therefore delaying water or gas breakthrough.

Due to the design simplicity of ICDs they can and have been installed on to various screen types with great success. They can also be used successfully as an inner screen completion within a failed screen gravel pack, stabilising water production to a manageable rate and completely stopping sand production, which in a marginal well can be the difference between being uneconomical to completely viable.

More efficient In multi-phase flow, autonomous inflow control devices (AICDs) can enhance phase filtering where phases have a higher mobility than the desired fluids. The device can be designed so that the undesired low viscosity water and/or gas phase is held back whilst the higher viscosity oil is favoured.

The net effect is more efficient crude production and improved water cut. This device has applications in oil reservoirs with gas cap, oil reservoirs with an aquifer drive and in SAGD application to reduce steam production.

Tendeka, the provider of completion and reservoir monitoring products and services to the upstream oil and gas industry, has developed a

This type of completion solution has been most prominent and highly successful in the Middle East complete suite of standalone screens, ICDs and AICDs within its portfolio and has successfully deployed these technologies for a number of operators in the North Sea. The company recognises that although such technology may be well established, and in some cases deemed a commodity, sand control still requires to be considered properly by experts in the field.

Its bespoke high quality standalone screens exceed the standards set in the industry (ISO 17824) and are relatively simple to deploy through being made from proven components. It currently has the largest single site screen manufacturing capacity and shortest lead times available in today’s market.

Tendeka’s FloRight-Ultra™ ICD screen range is based on the company’s premium sand control screen FloMax-Ultra™ using an innovative press-fit assembly method to ensure the highest burst and collapse ratings of the premium mesh layers. This premium screen design uses a multi-layer design for support, drainage, filtration, convergence and protection. The six, field-adjustable, ICDs are mounted underneath the end adapter housing of the screen assembly to promote uniform production or injection from the entire payzone of the well.

Additionally, FloRight-Ultra™ screens can be supplied with the FloCheck™ ICD Valve. The valve is a convergence technology based on several important lessons learned during the last decade of ICD installations: 6 Deploying inner strings is sometimes mandated due to poor hole conditions 6 Low bottom hole pressure may cause differential sticking due to inability to circulate 6 Low bottom hole pressure may lead to multiple runs with inner string to set mechanical packers 6 Inner strings take time to run and may increase weight and stiffness 6 Fluid losses during running of upper completion is difficult and costly to control Without the additional cost and time of running an inner string, this patented device allows for circulation to permit the setting of mechanical

packers, enables the spotting of breakers and spacers prior to pulling out and provides fluid loss control while running the upper completion. This has enabled ICD completions to be installed during periods of high well losses without having to pump a loss control material (LCM).

FloCheck is a simple but effective system.

When used in conjunction with ICD technology it closes off the nozzle, thus preventing any fluid loss while running in hole. Once production is initiated the ball merely comes off seat and the cage is shortly eroded on flow, allowing for both production and injection.

Combinations of these sand control technologies have found favour in the North Sea, resulting in recent multiple major contracts for ICD completions. Tendeka’s ICD and AICD technologies offer an even, consistent flow of fluid along each interval throughout the completion string, improving performance, efficiency and production, and can be combined with a sandscreen in an unconsolidated reservoir. The reservoir fluid passes from the formation through the screen and into the flow chamber, where flow is regulated by the ICD orifice. Along with other ICDs, the pressure drops in the production zone are equalised, yielding a more efficient completion.

In today’s competitive market place, oil and gas industry operators are continually searching to find new and improved means of working in a smarter manner and reducing costs. Such a commitment creates challenges and a requirement to rethink best practices at almost every stage of the process, especially as the industry seeks to exploit ever more difficult reserves.

A key question in the drive for enhanced production is how best to control and manage sand, and the introduction of a number of new technologies in this field have significantly improved performance with associated cost savings.

There are a number of methods for controlling and managing sand, however, the introduction of ICDs, to that list adds a further, credible option.

Traditionally used as an inflow balancing technology, it is clear that ICDs can also be deployed effectively to assist the control of sand production. They are a proven addition to the reservoir optimisation mainstream and offer new options for cost-effective completion designs and sand control. n

by Duncan Harper and Chris Rodger, Tendeka

Hunt Graham contract win in Saudi Arabia CORAC GROUP PLC announced that its subsidiary Hunt Graham Ltd has secured a significant contract to supply multiple heat exchangers to a major project in Saudi Arabia. The contact is valued in excess of US$2.4mn and is for five specialised heat exchanger units for delivery within one year.

According to a company statement, Hunt Graham succeeded in a competitive bid for this milestone project against its international peer group to secure the order.

70 Oil Review Middle East Issue Five 2013

The order was placed by VME Process, a US based Engineering, Procurement and Construction (EPC) company and a leading supplier of process systems to the Oil and Gas industry, through their Asia Pacific office in Singapore.

“We are delighted to be able to play a part in this project. This contract adds to Hunt Graham’s order book to give good visibility of future business and shows the value of our strategy to work with world leading

EPCs, designing and supplying high integrity products to selected end users.

This work extends the Group’s activities in Saudi Arabia, alongside Corac Energy Technologies’ gas field compressor project and demonstrates the group Group’s strategy of extending geographic presence and supporting key clients across the combined range of Corac Group business capabilities,” a company spokesman said in a statement.

www.oilreview.me

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Communications & IT

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GE’s industrial Internet is mostly about energy efficiency, and that’s good news for the oil and gas sector. Ian Roullier reports.

The power of

one per cent T

HE INCREASING LEVEL of data has been an unstoppable, seemingly uncontrollable trend throughout the Internet age – an estimated 2.5 quintillion bytes of data are generated every day according to IBM. But GE believes that ‘big data’ generated by machines, and the intelligent interpretation of that data, will potentially reshape the future of industry itself and is currently investing heavily in the technology and systems to make this new economic age a reality.

“The Internet will also transform global industries, joining human insight with machine intelligence,” the company said recently in the agenda for its Mind + Machines event. “Bringing minds and machines together has created something wholly new: the Industrial Internet – an open, global network that connects machines, people and data to enable better operations and smarter, faster decisions.”

The Industrial Internet has the potential to cut across every industry, many of which GE is intrinsically connected with, and fundamentally change the way they function.

“When we think about the products that we make, a jet engine or a gas turbine or oil and gas equipment, you’ve got material science that drives

72 Oil Review Middle East Issue Five 2013

Remote monitoring of rigs has a number of benefits

‘I think that every industrial company is going to be creeping into analytics’

performance data prognostics and capability and that today is added to data and information technology,” said GE chairman and CEO, Jeff Immelt, at the event that was held inside London’s Battersea Power Station.

The onus of the Industrial Internet is on smart machines, real-time data and advanced analytics.

The positive applications for the oil and gas industry are manifold. As the demand for energy rises and oil and gas reserves become increasingly difficult to access, the increased productivity that the Industrial Internet can help bring to the industry could prove vital.

“We decided maybe eight or nine years ago that the oil and gas industry was going to evolve in the same way the aviation industry evolved,” said Immelt. “There was going to be a more technical base and there was going to be room for somebody as a technical leader and aggregator, so we made big investments in the oil and gas space.”

GE is working in partnership with many oil and gas companies globally, offering sensor and control technology, optimisation and diagnostics to ensure the efficient operation and predict potential failures of critical machinery. One such company is BP, which is working with GE to ensure that the operation of its rotating machinery at its production facilities is maintained effectively. The equipment includes compressors, generators and critical pumps that are vital to ensure the safe extraction and transportation of oil and gas globally.

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Communications & IT

S15 ORME 5 2013 IT Feature 01_Layout 1 21/08/2013 18:28 Page 74

The Industrial Internet has the ability to cut across every sector of industry

The onus of the Industrial Internet is on smart machines, real-time data and advanced analytics By analysing sensor data such as vibration, rotor position, temperature, pressure flow and other parameters, GE is able to identify changes in the operating condition of the machine or determine that the machine is no longer performing at its optimal capacity. Identifying the early onset of abnormal operating conditions minimises disruption and avoids unnecessary periods of downtime.

To help extend the running period between overhauls without interruption, BP has deployed GE’s System1 and SmartSignal software across a number of its offshore production facilities. It is now able to remotely monitor its machinery and take advantage of support from any of GE’s dedicated remote monitoring centres around the world. Remote monitoring has a number of benefits, not least because it removes the need to bring extra staff on to the rig to undertake physical monitoring in an environment which can be plagued by hostile weather conditions. It also means that experts can be consulted remotely from anywhere around world, as required.

GE assists BP to harvest and manage large volumes of data from sensors installed on its offshore machines. The amount of data being

74 Oil Review Middle East Issue Five 2013

captured can be varied based on operating status and when a potential problem is identified so that an accurate diagnosis can be made and preemptive interventions taken.

GE, which currently employs a team of 9,000 software engineers globally, also manufactures subsea trees tailored for use in waters of all depths.

These can also be laden with sensors to provide customers with accurate, real-time data. “[It is] staffed with technology to control and monitor and make sure that the flow out of the wellhead is optimised in whatever respect you want to optimise it,” said Carlos Härtel, European managing director of GE’s Global Research Centre.

“It sits on the ocean floor maybe 3,000, 4,000 metres underneath the water level and has to operate for approximately 25 years safely.

“To make sure that you don’t have any disruptions, you want to take the data, send it back to the monitoring team and make sure that they have all the tools available to sense any minor disturbances to normal operations very quickly so they can take pre-emptive measures.

The subsea trees are also typically furnished with lots of sensors, including a wellhead sensor. The more you can put on them, the more you can learn, the better it is.”

GE has also developed its Measurement and Control Subsea Condition Monitoring system, also know as ‘The Cage’. Developed in Norway, the system sits on the sea floor or on subsea equipment and, via an array of sensors,

measures sound and electrical signals emitted from subsea equipment, often an early warning sign of developing leaks and other issues.

Engineers designed the ‘eardrum’ of the system from special crystals that respond to sound wave vibrations and convert them into electricity. A single device can listen to sounds within a 500 metres radius. “[It] is a system that is in a sense a giant ear that sits on the ocean floor and is listening to what the equipment has to tell it,” said Härtel. “So that means you are listening to electromagnetic waves and from those data you can infer what actually equipment is doing around you, rather than using a lot of sensors on that equipment itself.”

An array of attached carbon rods can also detect changes in the magnetic field generated by electrical cables, pumps, motors and other electrical equipment in a subsea environment, and spot ground faults or defective isolation. This sound information is sent to a seaborne control room where the data is analysed to help plan maintenance and component replacement programmes. The GE team is now developing a huge data library of sounds from existing subsea installations to add to the predictive capabilities of the system.

According to GE, the system can be 10,000 times more accurate than traditional mass balance systems that measure differences in the amount of oil and gas flowing through the pipes to detect leaks. The condition monitoring system is already working in the North Sea and off the coast of Africa.

“An acoustic signature from a piece of equipment is like a fingerprint from a human,” said Fabian Dawson, sales manager at GE Measurement and Control. “No two leaks or pumps are going to sound the same. We can filter out the background noise, like marine life, and listen only to things we want. You can determine the revolutions per minute of a compressor from the acoustic signal and then you can determine how hard it is working from the electrical signal. Taken together, they will tell you what the efficiency is.”

The synthesis of big data and decades of engineering experience forms the backbone of GE’s offering in the oil and gas sector. The sector presents many challenges, but with the advent of big data and the Industrial Internet there is much scope to eliminate variability of performance and increase uptime in oil and gas exploration and extraction.

“The harnessing of oil helped drive the Industrial Revolution,” GE’s Mind + Machines event agenda stated. “Now such transformative power is being driven by the next technological revolution, the Industrial Internet.”

This revolution may well comprehensively change not just industries, including the oil and gas sector, but also alter the very way companies function.

“The history of a big industrial company like GE is that we sell products to our companies and when they broke we would fix them. That’s still critically important, but I think the future’s all going to be about outcomes and performance,” said Immelt. “I think that every industrial company is going to be creeping into analytics because it’s the only way to guarantee that the products you sell are ultimately going to be successful.” n www.oilreview.me

S16 ORME 5 2013 DMS_Layout 1 21/08/2013 18:31 Page 75

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S16 ORME 5 2013 DMS_Layout 1 21/08/2013 18:31 Page 76

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Project Databank Compiled by Data Media Systems

OIL, GAS AND PETROCHEMICAL PROJECTS Project QP - Ras Laffan Aromatics plant

Sector Petrochemicals

Facility Aromatics

Oryx GTL Gas-To-Liquids (GTL) Plant Phase 2

Gas

Gas to Liquids (GTL) 1500000000

QP - Air Compressor Replacement at Mesaieed Refinery QP - Wellhead Scada & Cathodic Protection In Dukhan Field QP - Mesaieed Vapor Recovery System At Multi Product Berth (MPB) RasGas - Qatar Barzan Gas Field Development Project - Offshore - Phase 2 RasGas - Qatar Barzan Gas Field Development Project - Offshore - Phase 1 RasGas - Qatar Barzan Gas Field Development Project - Onshore - Phase 1 RasGas - Qatar Barzan Gas Field Development Project - Onshore - Phase 3 Mesaieed Refinery to BSV3 Station Jet Fuel Pipeline Ashghal - Sewage Pumping Stations Refurbishments

Gas Oil

Gas Processing Oil Production

Gas

Block D Exploration QP - SHELL/PETROCHINA - Block D Natural Gas Exploration QAPCO - Ethylene Plant Expansion 3 (EP3) - Phase 1 Qatar Petroleum Mesaieed Gas Integrated Sweetening Project (GISP) QP - NGL 1 & NGL 2 Plants Upgrade Ashghal - Inner Doha Resewerage Implementation Strategy (IDRIS) - (Overview) RasGas - Qatar Barzan Gas Field Development Project - Onshore - Phase 2 Qatar Petroleum - Bidirectional Pipeline Between KM and KS Laffan Refinery Company - Ras Laffan Condensate Refinery Expansion Shell - Al Karaana Petrochemical Complex - (Overview) Dolphin Energy - Export Gas Compression Facilities Upgrade RasGas - Qatar Barzan Gas Field Development Project (Overview) RasGas - Qatar Barzan Gas Field Development Q4-2022 QATARGAS - Plateau Maintenance Project Project - Offshore - Phase 3 Ras Laffan Diesel Hydrotreater and Sulphur Recovery Unit Qatar Petroleum - Centrifugal Air Compressor System Qatar Petroleum - Fuel Gas Supply to Dukhan QATARGAS - Jetty Boil Off Gas Recovery RasGas Company - Qatar Helium 2 Project QP - Combined SRU and AGR Projects at Mesaieed and Dukhan

50000000 225000000

Status Feasibility Study Feasibility Study EPC ITB EPC ITB

Start Date Q4-2012

Completion Date Q1-2018

Q2-2011

Q4-2017

Q2-2012 Q2-2012

Q2-2014 Q4-2014

Gas Processing

30000000

FEED ITB

Q3-2012

Q3-2015

Oil, Gas

Gas Production

700000000

Q2-2013

Q1-2017

800100000

Feasibility Study EPC

Gas

Oil, Gas

Gas Field Development Gas Field Development Gas Production

Q1-2007

Q4-2016

1700000000

EPC

Q1-2007

Q1-2014

3000000000

Feasibility Study EPC Feasibility Study EPC EPC

Q1-2018

Q1-2021

Pipeline Water, Pipeline

Gas Pumping Station

100000000 100000000

Q1-2010 Q1-2014

Q4-2014 Q3-2016

Oil Gas

Exploration Gas Exploration

200000000 500000000

Q1-2008 Q4-2009

Q3-2015 Q2-2015

Petrochemicals Gas

Ethylene 214000000 Gas Treatment Plant 200000000

EPC Q3-2010 Construction Q1-2010

Q3-2014 Q3-2013

Gas Water, Pipeline

Gas Processing Water

100000000 2700000000

Shelved EPC ITB

Q1-2011 Q3-2012

Q3-2014 Q3-2019

Oil, Gas

Gas Production

2000000000

EPC

Q1-2011

Q3-2014

Gas, Pipeline

Gas Pipeline

55000000

EPC ITB

Q2-2012

Q4-2014

Refining

Refinery

1500000000

EPC

Q4-2011

Q2-2016

Petrochemicals Gas

Petrochemical Plant 6000000000 Gas Production 250000000

FEED EPC

Q2-2004 Q1-2013

Q4-2018 Q4-2015

Gas

Gas Field Development Gas Production

8600000000

EPC

Q4-2007

Q4-2021

300000000

Feasibility Study

Q1-2017

Gas

Oil, Gas Gas

Budget 1000000000

2000000000

EPC

Q1-2008

Q2-2013

Refining

Liquefied Natural Gas (LNG) Hydrotreating

1000000000

EPC

Q2-2010

Q1-2014

Refining Pipeline Gas Gas Gas

Refinery Gas Gas Gathering Helium Sulphur Recovery

50000000 110000000 1000000000 500000000 1000000000

EPC ITB EPC EPC EPC EPC

Q2-2011 Q4-2008 Q1-2009 Q3-2009 Q1-2008

Q2-2014 Q2-2013 Q1-2014 Q1-2013 Q3-2013

S16 ORME 5 2013 DMS_Layout 1 21/08/2013 18:31 Page 78

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Project Focus Compiled by Data Media Systems

Project Summary Project Name

Qatar Petroleum - Centrifugal Air Compressor System

Name of Client

Qatar Petroleum (QP)

Budget ($ US)

50,000,000

Award Date

Q2-2013

Facility Type

Refinery

Status

EPC ITB

Start Date

Q2-2011

End Date

Q2-2014

Location

Mesaieed, Qatar

Project Backgrounds Qatar Petroleum (QP) plans to install centrifugal air compressor for its refinery at the Mesaieed Industrial Area.

Project Status May 2013

EPIC contract has still to be award.

17 Jun 2012

Bids have been submitted.

Aug 2011

The ITB for the EPC contract is expected to be issued soon.

Project Scope The scope of work will likely include:

■ Three centrifugal air compressors

■ Replacement of existing compressor system

■ Associated facilities

Project Finance Qatar Petroleum is the project client.

Project Contractors PQ

Bidders

Awarded

-

-

- Qatar Petroleum (QP)

Project Personnel Name

Howard Bijan

Designation

Manager

Company

Qatar Petroleum (Planning)

Phone

+974-4477-6555

Fax

+974-4483-1125

Address

Qatar Petroleum Qatar Petroleum Building Al Dafna Area PO Box 3212 Doha, Qatar

S16 ORME 5 2013 DMS_Layout 1 21/08/2013 18:31 Page 80

Project Focus Compiled by Data Media Systems

Project Summary Project Name

Qatar Petroleum Mesaieed Gas Integrated Sweetening Project (GISP)

Name of Client

Qatar Petroleum (QP)

Budget ($ US)

200,000,000

Award Date

Q1-2010

Facility Type

Gas Treatment Plant

Status

Construction

Start Date

Q1-2010

End Date

Q3-2013

Location

Mesaieed, Qatar

Project Status Qatar Petroleum is planning to set up a Gas Sweetening Integrated Plant, which will have capacity to process about 750 million cubic feet a day of gas.

80 Oil Review Middle East Issue Five 2013

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

JULY 13 Country

JUNE 13

VARIANCE

JULY 12

Land & Offshore

Land & Offshore

From Last Month

Land & Offshore

Land & Offshore

JUNE 12

From Last Month

VARIANCE

4 51 93 32 47 23 12 81 0 26 1 5 1 1 377

4 63 89 34 49 24 8 82 0 26 0 6 1 1 387

0 -5 4 -2 -2 -1 4 1 0 0 1 -1 0 0 -2

4 71 81 36 50 17 10 82 24 19 1 4 0 0 399

4 72 79 35 51 11 7 84 27 24 1 3 0 0 398

0 -1 2 1 -1 6 3 -2 -3 -6 0 1 0 0 0

49 51 16 3 119

48 63 15 5 131

-1 12 -1 2 12

45 71 9 2 127

41 72 10 2 125

-4 1 1 0 -2

Middle East BAHRAIN EGYPT IRAQ KUWAIT OMAN PAKISTAN QATAR SAUDI ARABIA SYRIA UAE - ABU DHABI UAE - DUBAI YEMEN JORDAN CYPRUS TOTAL

North Africa ALGERIA EGYPT LIBYA TUNISIA TOTAL

Source: Baker Hughes

82 Oil Review Middle East Issue Five 2013

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S17 ORME 5 2013 Arabic_Layout 1 21/08/2013 18:38 Page 84

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S17 ORME 5 2013 Arabic_Layout 1 21/08/2013 18:38 Page 85

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S17 ORME 5 2013 Arabic_Layout 1 21/08/2013 18:38 Page 86

S17 ORME 5 2013 Arabic_Layout 1 21/08/2013 18:38 Page 87

‫ﺗﺤﻠﻴﻼت‬

‫اﻟﻐﺎز ﻓﻲ اﻟﻤﻤﻠﻜﺔ اﻟﻌﺮﺑﻴﺔ اﻟﺴﻌﻮدﻳﺔ ﻫﻞ ﻳﻔﻘﺪ ﺑﺮﻳﻘﻪ أم ﻳﺜﺒﺖ ﻗﻴﻤﺘﻪ؟‬

2012 ‘ ¬dɪàcG ó©H …ôëÑdG ¿GQÉc π≤M

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‫أراﻣﻜﻮ اﻟﺴﻌﻮدﻳﺔ ﺗﻌﺘﺰم ﺑﻨﺎء ﻣﺤﻄﺔ ﻏﺎز ﺟﺪﻳﺪة ﺑﺎﻟﻔﺎﺿﻠﻲ‬

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‫ﻟﻤﺤﺎﻣﻞ اﻟﺴﻴﺎرات واﻟﺼﻨﺎﻋﻴﺔ‬

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S17 ORME 5 2013 Arabic_Layout 1 21/08/2013 18:38 Page 89

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‫اﻟﻘﺴﻢ اﻟﻌﺮﺑﻲ‬ 4

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‫ﻣﻠﺨﺺ ﻣﺤﺘﻮﻳﺎت اﻟﻘﺴﻢ اﻹﻧﺠﻠﻴﺰي‬ :á°UÉN ôjQÉ≤J .ôØ◊G äÉ«æ≤J ,ôjƒ£Jh ÖjQóJ ,äGQÉμàHG ,äÉYÓ£à°SG ,¥Gô©dG ......................................................................................................................................................................................................

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:äÉeƒ∏©ŸG É«LƒdƒæμJh ä’É°üJ’G .ájôëÑdG ä’É°üJ’G ......................................................................................................................................................................................................

:¢VQÉ©e .2013 ÉHhQhGC Qƒ°ûahGC ,2013 RɨdGh §Øæ∏d π«HQGE ¢Vô©e

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

Hart BV. ........................................................................51

R STAHL MIDDLE EAST FZE......................................39

AAggreko Middle East Ltd. ......................................32

Hi-Force Ltd. ................................................................11

RBV Energy ..................................................................35

Al Rashed Fasteners ..................................................47

IIR Exhibitions (MEE) ................................................76

Sabin Metal Corporation ............................................9

ALAA Industrial Equipment Factory ......................65

IIR Exhibitions (PWME) ............................................78

Saga PCE Pte Ltd. ......................................................69

Alderley FZE (ADIPEC 2013)....................................66

Inmarco Industries FZC ............................................40

Schlumberger Oilfield Mktg Communications ......2

AlMansoori Specialized Engineering ....................30

Inova Geophysical Equipment Limited ................50

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

CompAir Middle East ................................................57

Jotun Paints UAE Limited LLC ..................................5

Shree Steel Overseas FZCO........................................4

CWC........................................................................83, 86

Kaeser Kompressoren FZE........................................43

Society of Petroleum Engineers ......................26, 33

DMG World Media Dubai Ltd. (ADIPEC 2013) ....84

Marelli Motori SPA ....................................................21

Suraj Limited ..............................................................67

DMS GLOBAL (ISA) ....................................................80

Messe Düsseldorf GmbH ..........................................17

T.D. Williamson SA ....................................................15

Duferco ........................................................................41

Metscco Heavy Steel Industries Co. Ltd...............91

Techma FZCO ......................................................62, 73

Emerson Process Management

Middle East Tubular Services Ltd. ..........................24

Technip - Region Middle East ................................63

(ADIPEC 2013) ..............................................................7

Mineral Circles Bearings ..........................................38

Tendeka ........................................................................59

Expotim International Fair ORG. INC

Nylacast........................................................................65

Timberland ..................................................................23

(Erbil Oil&Gas) ............................................................36

OKI Printing Solutions ..............................................47

TMK Middle East ........................................................52

FourQuest Energy Inc ................................................45

Oman Cement Company ..........................................31

Top Oil Field Industries Ltd. FZC ............................61

FrontierMEDEX............................................................75

PM Piping ....................................................................49

Trade House TMK ......................................................29

Global Pipe Company................................................35

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

Trans Asia Pipeline Services FZC ..........................40

S17 ORME 5 2013 Arabic_Layout 1 21/08/2013 18:39 Page 91

S17 ORME 5 2013 Arabic_Layout 1 21/08/2013 18:39 Page 92