Oil Review Middle East issue 1 2012

ORME 1 2012 Cover_ORMETHREE05COVER.qxd 31/01/2012 12:09 Page 1

Vol 15 Issue One 2012

www.oilreview.me

Oil Review Middle East - Volume 15 - Issue One 2012

UK £10, USA $16.50

Kingdom’s output ‘ close to capacity’ Troubled times in Algeria Bahrain lines up major events Adnoc to tender for oil concession renewal Decommissioning - dealing with ageing assets

SABIC - going from strength to strength See us these events

Unlocking reservoir potential Offshore access bridges the gap PDO to tackle technology challenges

www.oilreview.me

Almost US$20 trillion will be required to build the global oil and natural gas infrastructure to meet expected energy demand in 2035, Abdullah Bin Hamad Al Attiyah, president of Qatar’s Administrative Control and Transparency Authority, said recently.

See page 6

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S01 ORME 1 2012 Start_Layout 1 31/01/2012 14:37 Page 5

Vol 15 Issue One 2012

Contents

www.oilreview.me

UK £10, USA $16.50

SABIC - going from strength to strength

Kingdom’s output ‘ close to capacity’ Troubled times in Algeria Bahrain lines up major events

Columns

Adnoc to tender for oil concession renewal Decommissioning - dealing with ageing assets

6

Industry news and executives’ calendar

See us these events

Unlocking reservoir potential Offshore access bridges the gap PDO to tackle technology challenges

Analysis 14

Column

The first of what will be a regular column from specialists Exclusive Analysis looks at recent unrest in Algeria and its effect on the oil and gas sector.

l na gio r

Almost US$20 trillion will be required to build the global oil and natural gas infrastructure to meet expected energy demand in 2035, Abdullah Bin Hamad Al Attiyah, president of Qatar’s Administrative Control and Transparency Authority, said recently.

See page 6

re cto e th s se 7 9 ing ga 19 rv & Se oil nce si

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16

Outlook

Saudi Arabia’s downstream champion looks to the future.

See page 42.

Our special correspondent looks at growth prospects for the regional oil and gas sector.

22

Decommissioning Why lessons learned in the North Sea can be shared in the region.

Editor’s note

Country Focus 24

Saudi Arabia

The Kingdom has placed a strong emphasis on expansion of its downstream sector.

Exploration 28

Developments A round-up of exploration and project news from around the region.

Gas 34

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

Petrochemicals

SAUDI BASIC INDUSTRIES Corporation (SABIC) is hoping to bolster its increasingly global reputation in 2012 - but it faces key challenges in the year ahead, including anti dumping measures and potential feedstock issues.

The Saudi downstream champion, 70 per cent owned by the Saudi government, is already one of the world’s top manufacturers and suppliers of chemicals, fertilisers, plastics and metals. And it expects more of the same this year despite the bumpy conditions in troubled markets such as Europe.

Our look at the company’s prospects starts on page 42. Staying with petrochemicals, we also look at Rabigh Refining & Petrochemicals (PetroRabigh), which has a critical year ahead with a vital decision on phase two expansion yet to be finalised. And we also analyse two recent reports which look at the growth agenda within the GCC petrochemicals sector, highlighting the development opportunities in the industry and the challenges that lie ahead. Also of interest is a new report that predicts Saudi Arabia will embark on US$215 billion worth of petroleum projects, with a heavy emphasis placed on the downstream sector. Elsewhere in the magazine, Moin Siddiqi takes a medium-term look at the region’s hydrocarbons resources, noting that increasing domestic energy consumption may reduce export potential over the next decade.

38

Analysis

Two reports look at the new growth agenda within the GGC petrochemicals sector.

42

Sabic Review

ESPs used in a non-traditional role helped profile production in a carbonate oilfield to unlock higher reservoir potential.

Despite the unpredictable global economic backdrop, Saudi Arabia’s downstream champion remains in bullish mood.

48

Petro Rabigh Review

64

Reservoir Management

69

Pipeline Technology

The largest joint-venture Saudi petrochemical company has a critical year ahead.

The prospect of working on a pressurised piping system can be daunting. But an innovative new technology can save both time and money.

Exhibitions and Conferences

Offshore Access

Saudi Safety & Security

There’s a smarter way to work using marine access.

52

The second SSS exhibition will focus on the protection of industrial, other commercial, residential and infrastructural assets.

56

Kuwait Oil & Gas

74

Information Technology 80

News and Developments The latest IT products and news for the regional oil and gas sector.

This year’s event will showcase the cutting edge technology being developed in Kuwait’s energy sector.

84

Rig Count

Technical Focus

Arabic Section

Innovations

Industry News Qatar

59

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

4 11

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

Publisher: Nick Fordham

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Oil Review Middle East Issue One 2012 5

Industry News & Events

S01 ORME 1 2012 Start_Layout 1 31/01/2012 14:37 Page 6

Global energy demand needs huge investment CLOSE TO US$20 trillion (Dh73.44 trillion) will be needed to build the global oil and natural gas infrastructure to meet expected energy demand in 2035, Abdullah Bin Hamad Al Attiyah, president of Qatar's Administrative Control and Transparency Authority, said in Abu Dhabi recently.

"On a standalone basis, the Mena [Middle East and North Africa] region will be asked to invest over US$100 billion every year," said Al Attiyah, a former Qatar energy minister, in his speech at an industry conference.

"Future production levels will be determined by the investment decision we make in the present. As such, we need to ensure that the industry has a stable business environment that will give them the confidence to make large-scale investments," Al Attiyah said, adding that a close and loyal relationship between the national oil companies and international oil companies is a requirement to ensure success in multi-billion dollar projects spread over many years.

He said that despite the macro-economic imbalances in Europe and the US and the threat to global economic growth, the energy demand will continue to grow rapidly under the leadership of emerging economies, especially China and India.

"According to the International Energy Agency, energy demand in Asia will almost double by 2035, while consumption in the OECD [Organisation for Economic Co-operation and Development] will remain almost constant, Non-OECD countries lead the growth in energy consumption," Al Attiyah said.

He added: "Their rapid economic development is expected to outweigh energy efficiency gains resulting in an overall increase in energy demand. At the same time, even though hydrocarbons remain the dominant source of energy, the energy mix gradually shifts away from oil and coal, while natural gas and renewable energies gain market share."

If oil trades between US$85-$95 per barrel range over the next decade, it will provide an adequate economic incentive for producers such as the UAE to continue investing in long-term sustainable production capacity, energy minister Mohammad Bin Dha'en Al Hameli said during an energy conference in Abu Dhabi yesterday.

"Indeed, in recent years the UAE has invested heavily across the hydrocarbon value chain and these investments are continuing," Al Hameli said. "However, these investments will materialise only if price levels are sufficient to justify commercial production from complex reservoirs," he added.

Al Attiyah

6 Oil Review Middle East Issue One 2012

New training facility for Iraq INTERNATIONAL LEARNING AND skills specialist Atlas has expanded the global footprint of facilities capable of delivering the groundbreaking new global training initiative IMIST for the oil and gas industry with the approval of the first centre in Iraq. The accreditation of the Al Delma facility in Basra City demonstrates Iraq’s commitment to developing its energy industry and creating a workforce trained to the globally recognised basic safety standard, IMIST online.

The Al Delma centre will be capable of delivering the programme to up to 250 people every day.

Bilal Mahmood, CEO of Al Delma said: “Long-term underinvestment in the development of our oil and gas personnel has meant considerable training is needed if we are to accomplish the goal of a safe and skilled workforce for the future.”

Developed by global oil and gas training standards body OPITO International, IMIST brings for the first time a standardised level of basic safety training to an estimated 1.5mn oil and gas workers worldwide. The training assesses basic safety knowledge in nine subject areas including risk assessment, asset integrity, the use of hazardous substances, working at height and mechanical lifting among other subjects.

The new centre will help train Iraqi oil and gas workers

Plenty of opportunities in support services COMPANY FORMATION SPECIALISTS Links Group anticipates demand for oil & gas support services in Qatar will accelerate over the next 12 months as major contractors seek to implement long-term maintenance agreements.

Following the completion of several oil & gas mega-projects in the Gulf state, operators are now directing their attention towards facility upkeep and are increasingly looking to the expertise of foreign companies to fulfil their equipment and manpower needs.

As the world’s top exporter of Liquefied Natural Gas (LNG), Qatar’s real GDP is expected to soar by around 21 per cent in 2011-2012, according to QNB Capital. The affiliate of Qatar National Bank says the surge in the hydrocarbon sector, combined with its anticipated budget surplus, will maintain Qatar’s position as the fastest growing economy. Oil & gas income was put at US$26.8 billion in 2010-2011 and is projected to hit an all time high of around US$38.3 billion in 2012.

While Qatar’s oil & gas sector shows no sign of slowing down, executives at Links Group say National Oil Companies (NOCs) are now entering a maintenance phase for their recently completed megaprojects such as RasGas, Qatargas, Shell Pearl GTL phase 1 and Dolphin project.

Speaking on the sidelines of the recent World Petroleum Exhibition in Doha, attended by 5,000 delegates and where some 400 international companies were exhibiting, Wayne Merrick Country Manager of Links Group in Qatar said there is a definite increase in interest for oil & gas support services particularly in the midstream and downstream sectors.

S02 ORME 1 2012 News & Calendar_Layout 1 31/01/2012 14:38 Page 7

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Industry News & Events

S02 ORME 1 2012 News & Calendar_Layout 1 31/01/2012 14:38 Page 8

Statoil steps up technology drive STATOIL HAS SINGLED out four business critical technologies as key to achieving the company’s growth ambitions. Statoil is boosting its R&D investments by 27 per cent and starting to plan Norway’s biggest centre for IOR technology.

In the period up to 2020 Statoil will maintain a high level of production on the Norwegian continental shelf while doubling its international production.

“The oil and gas industry is facing new technological challenges that differ from those we have dealt with so far. We will find the resources of the future at great oceanic depths,

in arctic areas where the conditions are extreme, and in new resources such as shale gas and shale oil for example. Statoil is well positioned to lead the continuing development of the oil and gas industry,” says Margareth Øvrum, executive vice president for Technology, Projects and Drilling.

Statoil is now stepping up its technology efforts in order to boost production, reduce energy consumption and support the company’s growth ambitions. Specifically this will mean tougher technology priorities, closer co-operation and the swifter implementation of technology.

www.statoil.com

Bahrain lines up major events BAHRAIN IS TO host several key international oil and gas conferences this year, once again confirming the country's status as a destination of repute for such events, Energy Minister Dr Abdulhussain Mirza has said.

According to a preliminary list released by the National Oil and Gas Authority (Noga), eight high-calibre events will be held from next month, beginning with the 14th Middle East Corrosion Conference and Exhibition from February 12 to 15.

"The event will see a line-up of experts, specialists and engineers, and the participation of a number of international oil companies in the exhibition," said Dr Mirza.

He said two events will be held in March, led by Geo 2012 from March 4 to 7 under the patronage of His Royal Highness Prime Minister Prince Khalifa bin Salman Al Khalifa. It will be followed by the Pipeline Operations and Integrity Management conference and exhibition between March 19 and 21.

The Middle East Petroleum and Gas Conference will be held from May 6 to 8 and will be followed by the Base Oil and Lubes Middle East (BLM 2012) Conference on May 9 and 10, a part of the Middle East Petroleum and Gas Week.

Petrotech 2012 will follow between May 20 and 23, also under the patronage of HRH the Premier.

The Middle East Chemical Week will be held from September 30 to October 3, while the Middle East Non Destructive Testing Conference and Exhibition will be held from October 7 to 10.

The last event of the year, Maintcon 2012, will be held from December 2 to 5.

"With the guidance of the wise leadership, Noga is keen to attract energy events and host them in Bahrain," said Dr Mirza.

"This will enhance Bahrain's position as an important destination in the Gulf and the Middle East for such global events that contribute to the development of professionals, particularly in the field of oil and gas."

ITF announces plans for technology investment ITF, THE GLOBAL oil and gas technology facilitator, has announced the challenges that its membership of operator and service companies want to see tackled as priorities this year.

Up to 100 per cent funding will be available for the right solutions to some of the industry’s most pressing challenges and ITF aims to secure around US$75mn investment directly from its members over the next three years.

A series of workshops will be held in international locations throughout the year on the top global priorities including:

6 Unconventional reservoir characterisation

6 Heavy oil 6 Subsea (including subsea power,

Aramco trading to spur global petroleum product sales ARAMCO TRADING, A wholly-owned company subsidiary, geared up and began commercial operations Jan. 1, 2012, as Saudi Aramco’s downstream investment portfolio expands in-Kingdom and overseas.

A statement on the company’s website said the new entity, formally established as Saudi Aramco Products Trading Company, will replace the Product Sales and Marketing Department (PSMD) in importing and exporting refined petroleum products, commonly known in the industry as ‘system balancing’ of refined petroleum products.

The formation of Aramco Trading was first announced in February 2011.

Since then, the company has been quick off the blocks preparing to commence business, establishing internal risk management and counterparty business management systems in line with industry best practices.

Aramco Trading will represent the company’s interest in sales and purchases of refined petroleum products such as condensates, naphtha, gasoline, middle distillate fuels, fuel oil and residual products and bulk petrochemical products.

The formation of Aramco Trading was first announced in February 2011. www.saudiaramco.com

8 Oil Review Middle East Issue One 2012

extra long tie-backs, produced water, separation and cleaning and replacement of valve actuators) 6 Down hole pressure and temperature monitoring The first Technology Challenge Workshop on unconventional reservoir characterisation will take place in Aberdeen on 13 March where members will prepare a roadmap to define the issues ahead of a further workshop in Houston in June. A global call for proposals will then be issued inviting technology developers to submit their innovative solutions. The organisation tasked with driving new technology solutions also revealed that it will be establishing membership clusters in the Middle East, Australia, US and Europe to focus on the unique regional challenges and bring forward more specific Joint Industry Projects (JIPs).

S02 ORME 1 2012 News & Calendar_Layout 1 31/01/2012 14:38 Page 9

Industry News & Events

S02 ORME 1 2012 News & Calendar_Layout 1 31/01/2012 14:38 Page 10

Kuwait - 104 billion barrels “realistic”

Kingdom’s output close to capacity

DR. HANI AL-GHAOS, a Kuwaiti economist, said recently the estimates that put the country's proven oil reserves at 104 billion barrels are "very realistic."

"The Burgan oilfield has abundant quantities of reserves," Al-Ghaos told a symposium held by Kuwait Economic Society (KES) under the theme of ‘Kuwait 2012 - Economic Outlook.

"The exploitation of the expertise, cost-effective methods and hitech are the key to better development of the oil sector," he stressed.

"The global energy giants resort to mergers and takeovers of other companies in order to maximize benefit from the advanced technologies," Al-Ghos pointed out.

He said he expects that 2012 will be the year of "unconventional oil crudes," noting that there were very promising scientific achievements in this domain.

Dealing with Kuwait's daily consumption of oil, Dr. Al-Ghaos said it amounts to 300,000 barrels out of which 50,000 barrels go to the transport sector.

On his part, CEO of Kuwait Financial Centre (Markaz) Manaf AlHajeri affirmed the strength of Kuwait's financial position.

However, he criticised Kuwait Stock Exchange, saying it no longer plays its role as a catalyst of investment and a link between investors and capitalists.

“KES is a professional and intellectual NGO initiative designed to catalyse sustainable economic development through building partnerships between civil society, private sector and policymakers.”

SAUDI ARABIA IS nearing its comfortable operational production limits and may struggle to do much to make up for shortages that arise from new sanctions imposed on Iran by the West, Gulf-based sources said.

Could Saudi Arabia meet increased demand?

The kingdom, now pumping just under record rates of 10mn barrels per day, has poured billions of dollars into its vast oil fields, which on paper should ensure it has the ability to ramp up to 12.5mn bpd.

Long-standing oil policy by Riyadh sets aside some 1.5mn bpd as protective spare capacity.

But industry sources said pumping anywhere near the declared production capacity might involve extracting heavy crudes the market might not want.

It would also be difficult to sustain higher rates for lengthy periods.

"There is very little unused capacity in the Gulf," said an oil official in the region. "Saudi Arabia could comfortably manage an extra 500,000 barrels a day or so and, if pushed, could go up to 11mn (barrels a day)."

A steady rate beyond 10mn bpd would offer immediate relief to world oil markets, but it would take the kingdom's production to untested levels.

New president for ExxonMobil Qatar

Iran denies storing oil offshore

BARTON P CAHIR has been appointed as the president and general manager of ExxonMobil Qatar.

Cahir will be responsible for leading the interface of all ExxonMobilaffiliated activities in Qatar in partnership with Qatar Petroleum as well as joint ventures between Qatar Petroleum International and ExxonMobil abroad.

ExxonMobil said it is working to realise the full potential of Qatar’s energy industry.

An American and Irish citizen, Cahir holds a Bachelor of Science in Petroleum & Natural Gas Engineering from Penn State University in www.exxonmobil.com Pennsylvania.

He has worked for ExxonMobil for almost 20 years in the United States, Asia and the Middle East.

Commenting on his appointment Cahir said: “I have been given an incredible opportunity to work in Qatar and I look forward to working with, learning from, and sharing my experiences with, other leaders in Qatar who are actively participating in the overall development of this country. Qatar has been blessed with natural resources, and I believe the energy industry is a key sector for Qatar’s continued economic development.”

IRAN HAS NOT stored oil in tankers in the Gulf, and its crude exports have not been disrupted due to mounting international pressure over its disputed nuclear programme, an oil official told the semi-official Mehr News Agency recently.

In January, shipping sources told Reuters the volume of Iranian crude oil stored at sea had risen to as much as eight million barrels and was likely to increase further as the Islamic Republic struggles with sanctions and a seasonal refinery slowdown.

"There has been no disruption in Iran's crude exports through the Gulf... We have not stored oil in the Gulf because of sanctions as some foreign media reported," Pirouz Mousavi told Mehr.

"We do not have even one drop of oil [stored] in the Gulf... Iran's oil exports are taking place based on the Opec's policies."

Iran, Opec's second-largest oil producer after Saudi Arabia with output of about 3.5mn barrels per day, faces trade hurdles over its nuclear programme, which the United States and its allies say is aimed at building bombs. Iran says it needs nuclear technology to generate electricity.

European Union countries have agreed in principle to embargo imports of Iranian crude as part of the latest Western efforts to step up the heat on Tehran.

Temporary storage of crude on tankers at sea has been an effective means in recent years for Iran to hold cargoes until sales can be made while not interrupting oil field production.

Meanwhile, Iran's recent round of Gulf naval drills practised the armed forces' ability to close the Strait of Hormuz, a lawmaker on parliament's national security committee was cited by Mehr News as saying. The elite Revolutionary Guards Corp start naval exercises on January 27 in the Gulf with the aim of enhancing the country's ability to close the chokepoint into that body of water "in the shortest possible time when the situation requires it", Mehr cited Esmail Kowsari, a member of parliament's National Security and Foreign Policy Committee, as saying in a report

10 Oil Review Middle East Issue One 2012

S02 ORME 1 2012 News & Calendar_Layout 1 31/01/2012 14:38 Page 11

Innovative excellence for the oil and gas industry Baumer combines original Bourdon quality with technical progress

www.baumer.com/oil-gas The Baumer Group, an internationally leading Swiss manufacturer of sensors and measuring instruments for factory and process automation, has expanded its international sales presence with a new subsidiary in the United Arab Emirates.

Baumer Middle East FZE in Dubai will draw on the decade-long, successful market presence of the Bourdon brand. „We are continuing the global experience and expertise of Bourdon-Haenni, a member of the Baumer Group as competence center for mechanical measuring instruments since 2005, at our location in Dubai.

Together with selected local sales partners, we offer many value-added services in different places. Our customers, particularly in the oil & gas and water treatment

industries, profit from a local and qualified contact point for competent service for all Baumer products and services”, pointed out Rüdiger Förster, President of Sales & Marketing of the Baumer Group.

Baumer is a rreliable eliable partner for international and demanding customers A worldwide sales presence with a wide product and technology portfolio as well as development and production locations in Germany, France, Denmark, Switzerland and India enable flexible completion of international and complex projects. As a result, Baumer has established itself as a reliable partner for internationally operating and demanding customers. For decades Baumer, under the brand name of Bourdon, has

been working closely with world-renowned oil companies in the extraction, transport and processing. Following a long and intensive cooperation, for instance the TOTAL Group relies on Baumer as a main supplier for diaphragm seals and pressure gauges. „Baumer Middle East will use this knowhow, Bourdon‘s market presence of more than 160 years as well as the worldwide network together with a professional and highly motivated team on site to strengthen customer support in the region even more”, announced Dr. Amer Tarraf, the new Managing Director of Baumer Middle East FZE. After all, the fast growing markets in the Middle East offer promising prospects due to an increasing demand for customized and innovative quality solutions.

Baumer Middle East ast FZE · JAFZA 16 · PP.O. ..O. Box 261729 · UAE-Dubai U · Phone +971 4 887 67 55 · Fax Fax +971 4 887 67 56 · sales.ae@baumer.com sales.ae@baumer.com · www.baumer.com www.baumer.com

Industry News & Events

S02 ORME 1 2012 News & Calendar_Layout 1 31/01/2012 14:38 Page 12

FEBRUARY 2012

12-15

Kuwait Oil & Gas

KUWAIT

www.the cwcgroup.com

14-15

ME-Tech

DUBAI

www.europetro.com

20-22

SPE North Africa Technical Conference

CAIRO

www.spe.org

21-23

Offshore Asia

KUALA LUMPUR

www.offshoreasiaevent.com

26-29

Saudi Oil & Gas

RIYADH

www.recexpo.com

27-29

Offshore Arabia

DUBAI

www.offshorearabia.ae

28-1 March

Protex Arabia

JEDDAH

www.thecwcgroup.com

4-6

Saudi Safety & Security

DAMMAM

www.sss-arabia.com

4-7

GEO 2012

MANAMA

www.geo2012.com

6-7

Saudi Downstream

JUBAIL

www.saudidownstream.com

11-15

7th Annual Asset Integrity Management Week

ABU DHABI

www.iqpc.com

13-15

Interspill 2012

LONDON

www.interspill2012.com

25-28

Middle East Downstream Week

ABU DHABI

www.wraconferences.com

25-29

SOGAT 2012

ABU DHABI

www.sogat.org

27-29

SPE Intelligent Energy International

UTRECHT

www.intelligentenergyevent.com

MARCH 2012

APRIL 2012

2-4

SPE HSE & Security Conference

ABU DHABI

www.ipieca.org

2-5

Syroil 2012

DAMASCUS

www.syroil.com

16-18

Oil and Gas West Asia

MUSCAT

www.ogwaexpo.com

30-3 May

Offshore Technology Conference

HOUSTON

www.otcnet.org

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

Basra exhibitors break records THE 2ND BASRA Oil & Gas, organized by Expotim International Fair Organizations INC and Pyramids International Group, concluded last November with record exhibitor and visitor numbers. The 2011 edition of the largest oil & gas show in Iraq welcomed 17,000 visitors from over 40 countries emphasising its position as an international exhibition.

This was the largest oil & gas event ever held in Iraq. The top five visiting countries to this year’s Edition, after UAE, were, Jordan, Saudi Arabia, Iran, and Turkey.

Being officially supported by the Ministry of Oil, the event had a great impact by being the foremost platform of the the oil & gas industry of Iraq with both its exhibition and conference sections.

Only a handful of exhibitors failed to attend the event because of security concerns, a spokeswoman for Expotim International told Oil Review, namely Shell, ENI, BP and ExxonMobil. Many of the industry’s leading players did attend however, including Samsung, Mitsubishi, Cameron, FMC Technologies, www.basraoilgas.com Tenaris, SGS, CNPC, Emerson Process Management, General Electric, Honeywell and Siemens.

The conference section was held concurrently with the exhibition, with

12 Oil Review Middle East Issue One 2012

the theme ‘Iraq on Track in Contributing to Future World Energy Supply’ on 26th and 27th November. The effective participation of Ministry of Oil officials as presenters in the first session attracted great interest.

Their presentations included: ‘The Industry’s Workflow, The Oil Domain – Oil Production and Refining, The Gas Domain – Gas Processing, The Infrastructures of the Industry, Oil & Gas and Products Disposal (Local and Exports).

The credibility of the event has been furrther enhanced by the audit that has been made during the event by BPA worldwide. Being a candidate for UFI membership, Basra International Oil & Gas Conference and Exhibition is unique in terms of its compliance with international standards. It is the first time in Iraq that an event has been audited.

The event will be held again, between 6-9 December at the same venue, the show organisers said.

Expotim International also organised an oil and gas event in Erbil last December. Although not as well attended as the Basra show, the organisers have scheduled another event for this year, to be held from 3-6 September at Erbil International Fairground.

S03 ORME 1 2012 Analysis 01_Layout 1 31/01/2012 14:41 Page 13

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S03 ORME 1 2012 Analysis 01_Layout 1 31/01/2012 14:41 Page 14

Analysis

Continuing civil unrest and political risks in Algeria will inevitably have some impact on the oil and gas sector, say experts from specialist intelligence company, Exclusive Analysis.

Troubling times

in Algeria S

PONTANEOUS AND VIOLENT unrest among disorganised groups and urban youth angry with the government is almost a daily occurrence in Algeria.

Motives include an unemployment rate unofficially estimated to be as high as 70 per cent among youths, lack of affordable housing, services and infrastructure failures, rising food prices and increasing political disengagement over a perception that political parties are ineffective and that the military holds the only real political power.

November 2011 alone saw fighting over access to housing among residents of an Algiers suburb, protests in Tizi Ouzou demanding road repairs and riots and looting in Mostaghanem. Since 6th January, protesters in the town of Laghouat have been holding sit-ins and demonstrations against the state's housing policy. On 14 January, unemployed protesters near Hassi R'mel, Algeria's largest gas field, located in Laghouat Province, blocked the roads leading to the offices of gas firms in the field. We assess that, at least in the coming three years, the Algerian government will be unable to meet the demands of protesters in Laghouat and in other Algerian provinces for employment and better quality housing. This makes it likely that protests over these issues will continue.

November 2009 defeat by Egypt, for example, prompted looting of offices belonging to Egyptian companies. Smaller towns along the coast and in the interior are more likely to see roadblocks or occupations of municipal buildings. Foreign companies that employ large numbers of non-Algerians are at particular risk of property damage and disruption.

Disruption

Islamist party Movement for a Society of Peace's (MSP) withdrawal from the ruling coalition in January 2012, increases the risk of government overthrow after mid-2012. The move suggests MSP believes the coalition with the FLN and RND parties is vulnerable to being removed from power, either through legislative elections in May 2012 or large-scale, prolonged civil unrest.

Several other factors would further increase political instability risks in the three-year outlook. First, smooth political transitions in post-revolution Libya and Tunisia would encourage a broader section of the populace to join protests, while Algerian opposition groups would find external support from these newlyformed governments. Second, any delay or failure to liberalise the political arena and stage transparent and fair legislative elections in May

Protests in towns where Laghouat residents have tribal connections, such as Ouargla, Hassi R'mel and Hassi Messaoud, are increasingly likely.

These would likely cause some disruption to firms that operate in the area. These firms are likely to come under more pressure to increase the employment of locals. In the unlikely event that the state uses lethal force against protesters, they would very likely spread rapidly and target water pumping facilities as well as roads to local airports. Foreign workers would also be at increased risk of attack by protesters.

In major cities, a culture of youth hooliganism means that even seemingly mundane events risk degenerating into riots and property damage. The Algerian football team's

14 Oil Review Middle East Issue One 2012

2012, or Islamist parties being refused participation in the new parliament, would potentially trigger sustained and widespread unrest, lead or joined by MSP and other Islamist parties. President Bouteflika has promised reforms next year, but may well be impeded by senior military officers protecting the status quo and have reversed previous reform efforts.

Finally, Algeria is entering a succession period during which the government is likely to be distracted by intra-elite fighting for control of the presidency and key state revenue streams (e.g. state energy company Sonatrach). An attempt by the military-security apparatus to impose a successor to ailing President Bouteflika (e.g. Prime Minister Ouyahia) would risk further mobilising the public against the military. Bouteflika has been in power for almost 13 years and is the figurehead of the military-dominated state that has been in power since Algeria's 1962 independence.

Strategic facilities A combination of the above would probably escalate the scale and intensity of unrest. However, for political stability to be threatened, we would also expect to see unions politicising their demands and taking coordinated strike action, joined by organisations like Algerian League for the Defence of Human Rights (LADDH), Sonatrach employees and student groups, targeting the energy and other key sectors. In such a scenario, the government would be more likely to give orders to fire on civilians to prevent blockades of strategic facilities, raising the risk of security force defections. Only a subsequent security forces split, whereby some join protesters, would create the conditions whereby Bouteflika, or the entire state apparatus, could be dislodged; this process would probably involve significant violence. â&#x2013;

Exclusive Analysis Ltd is a specialist intelligence company that forecasts commercially relevant violent and political risks.

For further information see www-exclusive-analysis.com

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Analysis

The region remains a vital player on the supply-side of the hydrocarbons industry, although swelling domestic energy consumption may reduce the region’s export potential over the next decade, with upside future pressures on prices writes Moin Siddiqi

Medium-term outlook for

hydrocarbons resources T

HE GLOBAL OIL market is likely to remain tight over the medium term, with demand projected to outpace total supply. By contrast, global gas supply is projected to cover demand growth comfortably, which explains the recent decoupling of oil and gas prices.

Crude oil prices have continued to firm since the autumn of 2010, despite volatility of demand and heightened concerns about a ‘double-dip’ recession in the Euro area. The International Monetary Fund (IMF) warns: “The global economy is in a dangerous new phase. Global activity has weakened and become more uneven, confidence has fallen sharply recently and downside risks are growing.” The projections for the 2012 average oil price diverge from US$90/barrel (Economist Intelligence Unit); US$100 (IMF); US$120 (Goldman Sachs); and there is a “onein-four chance of a spike” to US$150, according to Citigroup. The average price last year was US$103/barrel, up one-third from 2009 level of US$79.

Growing tensions over Western sanctions against Iran’s nuclear programme and any serious disruption of oil exports from the Strait of Hormuz could fuel a price explosion, thus representing a threat to the global economy. On the other hand, a lessening of geopolitical risk in the Middle East and the return of Libyan production, along with recession in Europe and

slowdown in China, will take the pressure off demand, thereby allowing for price corrections during 2012. Looking ahead, the sustained robust growth of emerging Asia and the anticipated maturing of oilfields in major producing regions (excepting MENA) have renewed concerns that oil markets could be entering a period of greater scarcity.

Power generation remains the key driver behind gas demand growth New output Global production capacity is predicted to increase by 6.82mn barrels per day (bpd) by 2016, representing an average annual growth of 1.2 per cent, according to the International Energy Agency (IEA), Medium-Term Oil and Gas Markets 2011. About two-fifths of the capacity hike (2.72mn bpd) is expected to derive from non-OPEC producers, led by the expansions of production from North and South American countries (mainly Brazil, Canada, and the US).

Technological innovations are driving nonOPEC capacity expansion: eg US output should see an average annual growth of one per cent, underpinned by the expansion of light tight oil,

which uses similar techniques to those used to extract unconventional gas. The remainder of the capacity hike is expected to come from OPEC producers (4.1mn bpd), with the largest share coming from Iraq as oil facilities are steadily being restored. Despite a surge in output capacity, OPEC’s spare capacity as a share of global oil demand will fall over the medium term, as oil demand growth outpaces the growth in non-OPEC supply.

While current projections indicate supply tightness in the medium term, there are signs of some relief over the longer term. Firstly, oil reserves are largely adequate, indicating that recent oil discoveries and technologies have continued to evolve at a rapid pace. Thus, despite robust oil demand in the past decade (albeit until 2008), the ratio of proven reserves to oil consumption has actually risen. Secondly, the prospect of higher returns is encouraging international oil companies (IOCs) to invest more in upstream activities, which in turn, should lead to higher production capacity in the long term. More specifically, the IEA estimated that IOCs increased their upstream investment by 10-20 per cent in 2011 relative to 2010, with 2010 already having seen about 10 per cent growth.

Demand eating into exports The MENA is by far the major oil-producing region – in 2010 it produced about 36 per cent

Table 1: Crude Oil Production & Exports (mn barrels per day) MENA Producers Algeria Iran Iraq Kuwait Libya Oman Qatar Saudi Arabia UAE Yemen Regional Total

Average 2006-10 1.32 3.84 2.22 2.50 1.72 0.78 0.80 8.80 2.48 0.32 24.78

2011 1.20 3.60 2.70 2.50 0.45 0.90 0.80 9.30 2.50 0.20 24.15

Proj.

2012 1.20 3.70 3.10 2.50 ……

0.90 0.70 9.30 2.60 0.30 24.30

Exports 2011 0.70 2.00 2.10 1.50 ……

0.70 0.70 7.40 2.20 0.20 17.5

Proven reserves * End-2010 12.2 137.0 115// 101.5 46.4 5.5 25.9 264.5 97.8 2.7 808.6

Reserves/Production ratio ** 18.5 88.4 100+ 100+ 76.7 17.4 45.2 72.4 94.1 27.7 80-100

* Billions of barrels. ** R/P ratio (calculated in terms of years). // In late 2010, the Iraqi authorities announced revised figures for recoverable reserves to 143bn barrrels, based on new geological surveys and seismic data compiled by 'reputable' international oil companies (IOCs), an increase of 24 percent on BP's estimations.

Sources: National authorities; OPEC; BP; and IMF projections.

16 Oil Review Middle East Issue One 2012

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Analysis

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of the world’s oil, whilst its share in global oil consumption amounted to just one-tenth.

Nonetheless, the region’s share in global oil consumption has grown rapidly over the past decade – a reflection of industrialisation and rising population, but also supported by low oil prices (ie heavy fuel subsidies) in many countries. Particularly noticeable has been the oil usage in recent years: oil consumption growth in the Middle East outpaced that of other regions in 2009 and was basically at par with Asia’s consumption growth in 2010.

Gas market in equilibrium In 2011, global gas supply easily met the surge in demand, despite some localised shocks.

Excess gas production over 2009 coupled with robust growth of 7.3 per cent in 2010 were sufficient to cover the incremental demand of about 220 billion cubic meters (Bcm) in 2010, according to BP’s Statistical Review of World Energy 2011. World natural gas consumption reached an estimated 3,169 Bcm in 2010 (rebounding from a drop of 2.5 per cent in 2009) – the largest increase since 1984.

Liquefied natural gas (LNG) production increased – especially in Qatar – by 60 Bcm, and US shale gas production also rose by an estimated 50 Bcm in 2010.

Power generation remains the key driver behind gas demand growth as replacement of ‘coal fired’ power by ‘gas-fired’ power in the medium to long term is the most cost-effective way of reducing carbon dioxide emissions globally, as noted in Massachusetts Institute of Technology (MIT), The Future of Natural Gas – An Interdisciplinary MIT Study, 2010. The power sector is, however, sensitive to price variations, and with gas-fired plants competing in the margin with coal-fired plants; the former react very rapidly to price changes.

Shale gas extraction has so far been confined to the US, but there is growing interest in exploiting unconventional sources of gas across the globe, including Australia, Canada,

China, Germany, Hungary, India, Poland, Saudi Arabia and the UK. Moreover, empirical research suggests that shale gas production could affect gas prices and may explain the recent decoupling of US oil and gas prices.

A series of external events in early 2011 collectively impacted upon both supply and demand; extra supplies from Russia (the world’s second-biggest gas producer, after the US) and Algeria compensated for Libya’s disruption of pipeline and LNG exports to Italy, and the closure of nuclear power plants in Japan and Germany led to additional demand for natural gas and LNG.

Natural gas is a vital component of the MENA energy industry

Global reserves ‘ample’ Proven world’s gas reserves at end-2010 were estimated at 6.609 trillion cubic feet (tcf). The MENA region holds 45 per cent of global natural gas reserves, with high probabilities of new discoveries. Just three countries (Iran, Qatar, and Russia) possess more than half of the globe’s reserves. At current global extraction and production rates, today’s recoverable reserves (conventional and unconventional) could sustain production for 58.6 years, whereas total ‘probable’ resources – the recoverability of which is, however, uncertain and far more challenging – equal 250 years of current production. Worldwide gas supply is expected to comfortably meet global gas demand growth of 2.4 per cent per year during 2010-16, based on the IEA database.

Non-OECD countries are leading the surge in natural gas demand, whilst also contributing to

as much as 90 per cent of additional supplies.

The Middle East is expected to represent onefifth of the incremental gas consumption, which is projected to rise from an estimated 370 Bcm in 2010 to 470 Bcm by 2016. On the supplyside, MENA will be the second-largest contributor, adding 110–150 Bcm of new capacity, expected to come online between 2011 and 2016. The strongest growth will come from Qatar, Iran, and Saudi Arabia, but in the latter two, increased production will be largely channelled for domestic consumption.

Boosting regional capacity Natural gas is a vital component of the MENA energy industry, providing a comparative advantage to petrochemicals and aluminium producers thanks to ample supplies of cheap feedstock for these sectors. Whereas the region as a whole should remain a ‘net’ gas exporter over the medium term, soaring domestic consumption has meant that many producers are now facing supply constraints, which have led to reduced volumes being available for exports and higher dependency on liquid fuels for power generation. Some countries (namely Kuwait, Oman, Libya and the UAE) will continue to import gas.

Saudi Arabia’s gas output has risen steadily from 71.2 Bcm in 2005 to almost 84 Bcm in 2010, but supply has not kept pace with annual demand expanding at 79 per cent. The UKbased energy consultancy, Wood Mackenzie, expects total consumption to reach 15 billion cubic feet (Bcf) per day in 2025. The amount of oil burned in power stations has increased in recent years. To boost natural gas production capacity, Saudi Aramco has increased investment in new gas fields.

These include the Karan project, which is expected to yield 1.8 Bcf/day of natural gas from 2013; the Wasit project with a nameplate capacity of 2.5 Bcf/day by mid2014; the 1.5 Bcf /day Shaybah natural gas liquids (NGL) venture; one Bcf/day from the

Table 2: Global Oil Production Capacity (mn barrels per day, unless otherwise indicated) -------------------------------------------------Projections-------------------------------------------------------2010 2011 2012 2013 2014 2015 2016 Production capacity OPEC of which: Crude oil National gas liquids Non-OPEC TOTAL Memorandum items: Oil demand Call on OPEC oil * Implied OPEC spare capacity to oil demand (percent)

Annual growth Avg.; percent 2011-16 2006-10

41.1 35.7 5.3 52.7 93.8

40.2 34.3 5.9 53.3 93.5

40.8 34.4 6.3 54.2 95.0

42.6 35.9 6.7 54.2 96.8

43.9 36.9 7.0 54.3 98.2

45.0 37.7 7.3 55.1 100.1

45.3 37.9 7.4 55.4 100.7

1.6 1.0 5.6 0.8 1.2

88.0 35.3

89.3 36.0

90.6 36.4

91.9 37.7

93.1 38.8

94.2 39.1

95.3 39.9

1.3 2.1

6.6

4.7

4.8

5.3

5.5

6.2

5.6

* Calculated as the difference between oil demand and non-OPEC production.

Sources: IEA, Medium-Term Oil & Gas Markets 2011; and IMF projections.

18 Oil Review Middle East Issue One 2012

2.3 2.1 3.7 0.5 1.3

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Analysis

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Arabiyah gas field, as well as 800mn cubic feet per day from Hasbah gas field, expected online within four years.

The surge in Iran’s production from 81.5 Bcm in 2003 to 138.5 Bcm in 2010 derived from the completion of several phases of the South Pars gas field. According to the Ministry of Petroleum, South Pars (the same geological structure as Qatar’s North Field) will see investment of US$90 billion in both the upstream and downstream sectors and despite the international sanctions, development at South Pars continues – with some US$47

billion worth of projects currently underway, two-thirds of which are for the upstream sector.

Higher production The longer-term production target once the 25phase project is finished is 400 Bcm per year and annual gas revenue from the field could reach US$110 billion (based on oil prices averaging US$80/barrel), according to Iran’s Oil Minister, Massoud Mirkazemi. Amid global sanctions, Iran is relying mostly on local engineering and construction firms to complete the mega project on time.

Table 3: Major Gas Consumers in the MENA (bn cu metres/year); 2010 Production

Consumption

Balance 51.5 16.2 1.6 -2.8 96.3 0.0 -9.5 9.6

Proved reserves * 159.1 78.0 1045.7** 63.0 894.2 283.1 213.0 232.8

R/P ratio 56.0 36.0 100 + 100 + 100 + 95.5 100 + 62.1

Algeria Egypt Iran Kuwait Qatar Saudi Arabia UAE Others

80.4 61.3 138.5 11.6 116.7 83.9 51.0 59.0

28.9 45.1 136.9 14.4 20.4 83.9 60.5 49.4

Total MENA

602.4

439.5

162.9

2969.0

100 +

* Figures for end-2010 reported in trillion cubic feet. ** According to the latest official statistics, Iran's natgas reserves total 33.1 trillion cu m (or 1171 trillion cu ft) about 12 percent higher than the quoted BP figure.

Source: BP Statistical Review of World Energy, 2011.

Continuous higher production is urgently needed in Iran for gas reinjection to sustain oil output, as well as cope with growing domestic demand. Natural gas usage in power stations, the residential and commercial sectors and industries (especially petrochemicals) is increasing by seven per cent annually, underpinned by heavily subsidised prices (reported at US¢35 per million British thermal units), which are among the lowest in the world.

In 2010 Iran’s power-generating capacity of 61,000 MW was 56.8 per cent gas-fired, followed by crude oil at 40.8 per cent and hydropower 2.4 per cent, respectively.

Qatar, whose production has more than doubled since 2006 to 116.7 Bcm in 2010 (the region’s second-largest after Iran) has imposed a moratorium on new projects (excluding the Barzan development) until 2013/14. Other countries are developing their import capacity with pipelines from Turkmenistan to Iran, LNG import terminals in Dubai and Kuwait, and interregional pipelines from Qatar to Oman and the UAE. To sum up, the region is a vital source of both supply and demand for oil and gas. The general stability of the hydrocarbons industry depends heavily upon the region. However, with burgeoning domestic consumption, energy exports from major MENA producers will probably decline in future years, unless massive investments are poured into new oil and gas fields. ■

ADNOC to tender for oil concession renewal THE UAE'S ADCO oil concessions will be put to tender when they come up for renewal in 2014, the director-general of Abu Dhabi National Oil Company said recently.

The concessions system allows oil and gas producers to acquire equity hydrocarbons from the Opec member country.

Multinational companies, predominantly Western oil firms, have held large stakes in the concessions for decades, but the upcoming expiry of concessions could provide an opportunity for Asian firms to boost their presence.

"Abu Dhabi Company for Onshore Oil Operations (ADCO) concessions will be put to bidding because firms will be screened and those that meet the minimum requirements would be invited to bid," Abdulla Nasser Al Suwaidi said on the sidelines of an energy conference in Abu Dhabi.

"Later, any company that submits the best offer technically and on price, will www.adnoc.ae be chosen."

He said no firms had been selected yet but existing partners are

20 Oil Review Middle East Issue One 2012

among the potential bidders.

Statoil, the Norwegian state-controlled oil and gas company, will be among the participants in landmark competitions for Abu Dhabi oil concessions that are due to expire within a few years. Helge Lund, the chief executive of Statoil, said the company was interested in competing for new licences to produce oil from some of the emirate's largest onshore and offshore fields when the contracts expire, in 2014 and 2018 respectively.

"The reason why we are here is that this is one of the regions in which, long term, we would like to work towards a partnership position," Mr Lund said.

"We are positioning ourselves for the potential relicensing of the 2014 [onshore] concessions and the offshore concessions in 2018." When Abu Dhabi established its state oil concern, Abu Dhabi National Oil Company (ADNOC), in the 1970s, the Government directed it to form joint ventures with the western oil companies that had held the emirate's original oil leases since the 1930s.

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Analysis

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Aramco targets China as it looks to double refining capacity SAUDI ARAMCO PLANS to build refineries in China and Indonesia as part of a US$200 billion spending programme to double refining capacity and explore for oil and natural gas during the next decade.

Aramco is preparing for talks about ‘final terms’ for a Chinese refinery and is still waiting for ‘good terms to be put on the table’ for a processing plant in Indonesia, Chief Executive Officer Khalid al-Falih said in an interview. Aramco will probably decide soon about whether to invest in expanding a plant it operates jointly with Japan's Sumitomo Chemical Company, he said on January 14.

www.saudiaramco.com

Aramco, the world's largest crude exporter, is expanding refining and petrochemical production to meet domestic demand and export refined products that can fetch higher prices than oil. The company plans to boost its global refining capacity to eight million barrels a day in 10 years, including projects yet to be announced, Mr al-Falih said. "It's an aspiration for a longerterm growth objective," he said of the refining-capacity target in the interview at the company's headquarters in the eastern Saudi city of Dhahran.

Aramco also plans to invest in drilling for oil and gas inside the kingdom and in petrochemicals production and other downstream activities, he said.

The company is exploring for unconventional gas, including shale and tight gas, in the nation's northwestern region, Mr al- Falih told reporters on January 14.

Low gas prices are a "challenge" to developing these hard-to-reach deposits, he said. Aramco's capital spending will probably rise to more than US$20 billion a year if it develops unconventional gas, he said in the interview.

Aramco will invest US$90 billion in the next five years to increase refining capacity by 50 per cent to six million barrels a day in projects "that more or less have been identified," al- Falih said. Refining capacity in Saudi Arabia itself will rise to 3.46mn barrels a day in 2016 from 2.26mn barrels, according to a presentation Aramco officials made at a conference in Bahrain in October.

Saudi Arabia's crude oil production rate in December was 9.76 million barrels a day, the Opec said in a report yesterday, using the average of several external estimates.

Most of the capacity to be added above the five-year target will be at refineries in Asia, with the bulk of that in China, al-Falih said.

Aramco seeks to tap increasing consumption in China, Asia's biggest energy user, by forming joint ventures with local partners.

The CEO said he was confident about reaching final terms on a plant with China National Petroleum Corporation, that nation's largest energy producer, to be built in China's southern Yunnan province. The two companies have agreed on the scope of the project, including the refinery and marketing, he said.

Decommissioning - lessons learned in the North Sea can be shared in the region ONCE AN OIL field has reached the end of its viable life, arrangements must be made to decommission the oil field facilities and any supporting infrastructure. In the North Sea, decommissioning is still a relatively new part of the industry, and with a large number of ageing assets coming to the end of their field lives, thorough consideration of the decommissioning process is becoming increasingly important.

There are approximately 470 installations in the North Sea and around 10,000 km of pipelines and it is estimated that decommissioning these facilities will cost approximately US$36-45 billion between 2010 and 2040.

The requirements for decommissioning offshore installations in the North Sea is dictated by the OSPAR 98/3 decision and administered by the Department of Energy and Climate Change (DECC). It is required that all installations are entirely removed from the seabed, with the exception of a limited number that fall into a certain category which may be considered for derogation.

Pipelines, on the other hand, may be considered for decommissioning in-situ if it can be demonstrated through study and analysis that the pipeline has been sufficiently cleaned and that removal is not a practicable option. However, in all cases, it must be demonstrated, in an officially submitted

22 Oil Review Middle East Issue One 2012

Decommissioning Programme that is signed off by the Government, that all decommissioning options have been considered and have been assessed based on safety, environmental, technical, social and economic criteria. As the decommissioning industry grows in the Middle East, it is likely that similar standards and requirements will develop.

The decommissioning process for offshore installations and pipelines can be a complex one and the time taken to complete a decommissioning project should not be

underestimated.

Planning for decommissioning can start up to five years before cessation of production and if adequate cost provisioning is not made at this stage, then operators may find that when the time comes to decommission, the required funds are not available as money has been invested in other projects.

Independent specialist Jee has over 20 years experience in the oil and gas industry and can provide expert support throughout the decommissioning process. They have helped major operators in the preliminary stages with independent studies, provided support during the execution of works as client representatives offshore and can even help to update relevant documentation during the close-out process at the end of a project.

With a pragmatic approach, a thorough understanding of subsea systems and an indepth knowledge of decommissioning legislation Jee continue to support major operators successfully implement decommissioning projects in the North Sea. Decommissioning was heavily underestimated in the North Sea and only now is the scale of the task being realised. Lessons learned from the North Sea can be shared across the industry and applied in the Middle East region to help operators prepare for the removal of their ever ageing assets.

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Saudi Arabia

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A report by Global Investment House (Global) predicts that Saudi Arabia will embark on US$215 billion worth of petroleum projects with a heavy emphasis placed on the downstream sector

Saudi Arabia focusing heavily on

downstream industry

Ras Tanura Refinery

I

N ORDER TO continue to benefit from previous high oil prices, GCC countries and Saudi Arabia in particular are focused on expanding their output by adding various new products to their offerings. This will translate into a greater focus on investing in the downstream sector at home and aboard.

This new emphasis on the petrochemical industry has being help by the onset of the global economic crisis, making demand and, therefore, prices of petrochemical products plummeted to historic lows.

According to Global, Saudi Arabia has approximately 147 projects upcoming in the petroleum sector, with an estimated cumulative value of US$215 billion. The main bulk of these investments will be destined for petrochemical projects. AlixPartners have estimated that Sabic's future projects will total around US$48.2 billion.

Asia is set to play a crucial part of Saudi Arabia’s downstream focus and petrochemical makers such as Sabic and Saudi Aramco are boosting their exports to and investments in Asia, notably China, to meet rapidly rising demand for chemicals and plastics used in the production of industrial and consumer products.

Increasing refining capacity Saudi Aramco outlined its new downstream focus when Khalid al-Falih, President and CEO,

24 Oil Review Middle East Issue One 2012

Saudi Aramco, outlined the company’s plans to build multiple refineries across Asia as part of a US$200 billion spending program to double its refining capacity to 8mn barrels per day (bpd).

To achieve this ambitious target Aramco is set to embark on an aggressive expansion of its petrochemicals business. A key part of this will see a greater emphasis on establishing strategic ties with key partners, most notably with China Petrochemical and Chemical Corp (Sinopec Group). Al-Falih said: “Saudi Aramco is in the downstream for the long haul, and Sinopec is one company that shares our bullish outlook.”

“Saudi Aramco is in the downstream for the long haul, and Sinopec is one company that shares our bullish outlook.”

Khalid al-Falih The start of 2012 saw Aramco and Sinopec final sign an agreement to develop a refinery, Yanbu Aramco Sinopec Refining Co (YASREF), in the Saudi city of Yanbu at a cost of as much as US$10 billion. The 400,000 barrel-a-day plant

will probably begin operating in 2014.

Aramco will hold a 62.5 per cent stake and Sinopec will own the rest.

According to Al-Falih: “Yasref is uniquely placed to seize market opportunities, and it demonstrates our unwavering commitment to significantly grow our downstream portfolio, and in creating win-win partnerships for us and our stakeholders.”

Other additions to capacity will involve Aramco investing abroad, plans for new refineries in Jubail and Jizan and the revival of a plan to expand Ras Tanura, already the Middle East's largest refinery.

Aramco is considering expanding the Ras Tanura refinery al-Falih said. Ras Tanura is Aramco’s largest local refinery with a capacity to refine 550,000 barrels of oil a day.

One of the major upcoming projects is the Yanbu Integrated Refinery & Petrochemicals Complex that is currently in the study phase and has an estimated budget of US$20 billion.

Importantly, Yasref’s location next to Yanbu', and next to two of our other refineries, is ideal for supplying both overseas markets and the fast-growing western region of the Kingdom.

Another major upcoming project is the Jazan Refinery Project that has an estimated budget of US$7 billion. The plant will have a 400,000 barrel-a-day capacity.

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Saudi Arabia

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Asian demand Emerging markets are increasingly becoming the drivers of growth in the global economy as mature and developed markets struggle with slow or even negative growth. This is especially true for the petrochemicals industry, which is banking on emerging markets in Asia and elsewhere absorbing new capacity due to come on stream in the next few years.

Global believes “a major chunk of future demand growth will come from this region and should enable the GCC petrochemicals industry to find a ready market for the output of the aggressive capacity expansion projects currently underway at various locations.”

Most of the capacity to be added above the five-year target will be at refineries in Asia, with the bulk of that in China, said al-Falih.

Both Aramco and Sabic are looking to tap increasing consumption in China by forming joint ventures with local partners.

Aramco and Sinopec are in early talks to add a new refinery in China that can process as much as 300,000 barrels a day.

Al-Falih said he was confident about reaching final terms on a plant with China National Petroleum Corp. (CNPZ), that nation’s largest energy producer, to be built in southern Yunnan province. The companies have agreed on the scope of the project, including the refinery and marketing, he said.

Sinopec Group is also expanding its business portfolio and entering new markets around the globe. The company has nearly half of China’s total refining capacity, and accounts for threefourths of that nation’s crude oil trade.

Sabic signed a cooperation deal with Sinopec to explore opportunities in new petrochemical projects.

The agreement sets the foundation for a joint investment to build a new polycarbonate production complex with an annual production capacity of 260,000 metric tonnes. The new facility will be located at the Sinopec Sabic Tianjin Petrochemical Co., or SSTPC, complex in northern China's Tianjin city.

“Sabic and Sinopec’s aspirations are now focused on establishing long-term strategic cooperation that contributes towards enriching Saudi Arabia’s and China’s economies in the areas of scientific research, technology and innovation,

producers to outmanoeuvre high-cost players.

In consequence, capacity shutdowns are taking in developed markets such as the US and the EU as companies increasingly try to rationalise their capacity portfolio in order to compete more with the low-cost producers, the Global report said.

Capacity to grow

Khalid A. Al-Falih, President and CEO, Saudi Aramco

engineering and product marketing” said Prince Saud bin Abdullah bin Thenayan Al-Saud, Chairman of SABIC and the Royal Commission for Jubail and Yanbu.

Sabic, which revealed the plan first in May, last year, said the plant will be operational by 2015.

Other regions in Asia are also seen as important opportunities for Saudi companies to invest in the downstream industry.

Indonesia is a good example. Aramco’is planning to develop a refinery with state-run PT Pertamina (PERT) and the companies may build a 300,000 barrel-a-day refinery in Tuban in East Java. The US$8.8 billion plant may start operating in 2018. But all the final details have not been finalised. But “early indications are positive” said al-Falih.

Developed markets Petrochemicals capacity expansion in the developed markets, especially the US, has been muted since 2000. Natural gas prices which had averaged US$2/mmbtu throughout the 1990s have shot to highs of over US$13/mmbtu in 2008 and averaged around US$6/mmbtu in this decade.

With oil prices staying above US$70 per barrel, naphtha prices have also risen in tandem.

According to Global, European and US petrochemicals crackers have increasingly found it difficult to compete with low-cost Middle Eastern players. As petrochemicals are commodity products, price is often the single most distinguishing factor. This fact enables low-cost

Global said the total petrochemical regional capacity to increase at a CAGR of 2.9 per cent during 2011-13 with most of the additional production capacity from Saudi Arabia followed by Qatar. In terms of growth, the capacity expansion from Qatar is expected to increase at a CAGR of 13.4 per cent during 20011-13. This will reflect positively on the improvement in the regional market share i.e. 14.2 per cent in 2013 as compared to 10.3 per cent in 2010.

Feedstock role The GCC is currently experiencing a shortage of ethane, historically the prime feedstock for its petrochemical plants, due to the increased domestic demand to fuel other industries, primarily power, steel, and aluminium.

Moreover, the region is developing policies to give priority to domestic gas use over export, phase out price subsidies, and align domestic natural gas prices with export prices.

As a result, Global argues that some project owners such as Saudi Kayan and owners of future downstream petrochemical clusters in Saudi Arabia are moving away from ethane-based, export orientated petrochemical production and are now developing plans to produce a wider slate of highvalue specialty chemicals for the automotive, textile, electronic, construction, agricultural, and pharmaceutical industries.

Fertiliser capacity According to Global, regional fertiliser capacity to increase at a CAGR of 16.4 per cent during 200913 with most of the expansion of 13.3 million tonnes expected from Saudi Arabia followed by Oman and Qatar.

The major expansion in Saudi Arabia is mainly due to: 6 Availability of undisrupted supply of feedstock gas at highly subsidised prices.

6 Ongoing demand-supply gap in Asian & Far East markets.

6 Expectations of average prices of fertiliser products to remain strong.

These factors will lead the regional fertiliser sector to continue its growth with gross margins to remain at an average of 68 per cent during 2011-13, the Global report stated.

Outlook

A graph showing the growth of petrochemical production capacity in the GCC over an eight year period

26 Oil Review Middle East Issue One 2012

The downstream sector has a healthy future in Saudi Arabia and the wider GCC region. With the investments and refinery capacity upgrades that are taking place in Saudi Arabia the regions big petrochemical players will soon become one of the top five petrochemical companies in the world in the not too distant future. ■

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Circle Oil completes pipeline in Morocco

Iraq’s oil exports increased in December

CIRCLE OIL PLC provided an update regarding the construction of the new pipeline and associated infrastructure for its Rharb Basin permits in Morocco.

The construction phase of the new Sebou (DRJ)-Kenitra pipeline has been successfully completed.

The pipeline is now undergoing pressure testing prior to commissioning and the start up of increased gas delivery to local industry, which is expected to be completed at the end of January.

Construction of the new pipeline has been completed on budget.

Prof Chris Green, CEO, said: "I am delighted to be able to report the completion of the construction phase for our new pipeline in the Rharb.

Following completion of commissioning of the pipeline Circle and its partner can look forward to significantly increasing gas supplies and associated revenues to local industry through 2012.”

The total length of the pipeline is approximately 55km and has a design capacity of 23.5 MMscf/d. The pipeline has been connected to seven of the ten potential producing wells, with tie-in for the remaining wells scheduled for completion during the first quarter of 2012. These wells were discoveries made during the two previous drilling campaigns in 2008/09 and 2010/11.

Circle, through its wholly owned subsidiary, Circle Oil Maroc Ltd. holds a 75 per cent interest in the Sebou and Lalla Mimouna Permit Concessions with the remaining 25 per cent held by ONHYM. In addition, it holds a 60 per cent interest in the Oulad N'zala Permit Concession with the remaining 40 per cent held by ONHYM. Circle has a 75 per cent interest in the new 8-inch pipeline with the remaining 25 per cent held by ONHYM.

IRAQ'S OIL EXPORTS rose by 10,000 bpd in December, to 2.145mn bpd up from 2.135mn bpd in November, according to data from the State Oil Marketing Organization (SOMO).

The data was obtained by Platts, with the figures showing that Iraq's oil exports increased by 273,000 bpd in 2011 to average 2.165mn bpd, up from 1.892mn bpd in 2010.

The latest SOMO figures show oil Iraq exported more oil in December last year exports from northern Iraq slipping by 11,000 bpd in December, to 412,000 bpd from 423,000 bpd in November.

Oil exports from southern terminals rose by 21,000 bpd in December, to 1.733mn bpd from 1.712mn bpd in November.

Although oil export from Iraq has increased the level of crude oil production has in fact fallen in 2011. The latest data indicates that the country's oil production fell by 13,000 bpd in December, to 2.652mn bpd from 2.665mn bpd in November.

Crude oil production from Northern Iraq is estimated to have fallen by 55,000 bpd in December, to 677,000 bpd from 732,000 bpd in November. While, production from Iraq's southern oil fields was estimated to have risen by 42,000 bpd in December, to 1.975mn bpd from 1.933mn bpd in November.

Drilling at Qarn Alam Block 64 begins

Genel reveals Tawke oilfield upgrade

THE OMAN SUBSIDIARY of A drilling well US oil firm Harvest Natural in Oman Resources has commenced the drilling operations of the Al Ghubar North-A (AGN-A) exploration well on the Qarn Alam Block 64, onshore Oman.

This is the second of a two-well exploratory programme utilising the MB Petroleum Services LLC Rig 113 drilling unit.

The AGN-A well will test the Al Ghubar North structure, which is a large salt-supported high with stacked reservoir targets in the Barik, Miqrat and Amin reservoirs. The targets are 10 miles to the east and updip from the producing Barik field.

Mean prospective resources of 960 billion cubic feet (Bcf) of gas and 54mn barrels (MMbbls) of condensate in the Barik and 241 Bcf of gas in the Miqrat formation have been calculated by Harvest.

The geological chance of success for a discovery in this well is estimated by Harvest to be 23 per cent.

The AGN-A well will be drilled to a total vertical depth of approximately 10,300 feet to test coincident fault bounded dip closure at all three reservoir levels. Dry hole cost for the AGN-A well is US$8.1mn.

Harvest has an 80 per cent interest in Block 64 onshore Oman.

Block 64 has an area of 3,874 sq-km and was extracted from a preexisting block (PDO's Block 6) to accelerate exploration of gas.

GENEL ENERGY WILL embark on a plant and pipeline upgrade of the Tawke oilfield following a significant upgrade in the gross reserves of the field.

The upgrade will significantly increase the production capacity of the field from its current limit of 75,000 barrels a day to 100,000 barrels a day by the end of this year.

Daily output in November was 42,798 barrels. The December figure, still to be confirmed, was expected to be some 60,000 bpd.

The upgrading work will coincide with the anticipated drilling of five development wells on the field, the first of which was spudded at the end of December. The well will test the additional resource potential of the northern flank of the Tawke field.

Genel’s drive for increased production comes on the back of a report from a US-based company which put 2P reserves at 509mn barrels of oil, a 78 per cent leap on the 286mn barrels estimated in a November report.

“Gross proven, plus probable, plus possible reserves (3P) are now estimated at 876mn barrels of oil, an increase of 68 per cent on the previously reported figure,” Genel wrote in a company announcement.

Tony Hayward, chief executive of Genel Energy said: "The major plant and pipeline upgrade underlines our confidence in the huge potential of the Tawke field. We are delighted by the upward reserves revision which further reinforces our belief that these are genuinely world-class assets in an area of outstanding geological heritage."

Genel also highlighted that there could be yet more reserves within the field as it and its partners plan to drill Tawke Deep in the second half of the year, targeting another 200mn barrels of gross unrisked mean resources.

Genal added: “In addition, the current Peshkabir-1 exploration well, which is on the West Dohuk structure area of the Tawke licence, is targeting 304mn barrels of gross unrisked mean resources. Results are expected in the second quarter."

28 Oil Review Middle East Issue One 2012

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UAE oil export pipeline ready in 5 months

CNPC awarded first Afghan exploration deal

UAE OIL MINISTER Mohamed Bin Dhaen Al Hamli stated that the oil pipeline that will allow the country to export oil via Fujairah should be operational within six months.

"The pipeline is almost complete but hopefully it will be operational within five months, by May or June," Al Hamli was quoted as saying by Construction of the Adcop pipeline Zawya Dow Jones.

Hamli added: "the first tanker loaded will be in about five months time, ready for export," adding the project involves a lot of work as the pipeline has to be filled with crude and tested.

The pipeline is known as Abu Dhabi Crude Oil Pipeline (Adcop) and is being built for the Abu Dhabi government investment firm International Petroleum Investment Co. (IPIC). It will cost around US$3.29 billion.

The 400km pipeline will have the capacity to transport between 1.51.8mn barrels a day. It will enable Abu Dhabi to export as much as 70 per cent of its crude from Fujairah, where tankers will be able to pick up the oil instead of sailing into the Persian Gulf via the Strait of Hormuz, the narrow waterway watched over by Iran.

THE AFGHANISTAN CABINET awarded China National Petroleum Corporation (CNPC) a contract for oil exploration and extraction across the country.

The oil exploration and production deal, which will be the first given by Afghanistan to an international oil company after several decades, is for the development of oil blocks in the Amu Darya basin in the north-west region of the country.

CNPC in partnership with a local company Watan Group will develop three oil fields, Kashkari, Bazarkhami and Zamarudsay, which is estimated to hold around 87mn barrels of oil.

"The Afghan cabinet has ordered mines minister Wahidullah Shahrani to sign an oil exploration contract for Amu Darya with China National Petroleum Corporation," the Afghanistan president's office said in a statement.

Under the deal, CNPC will pay a 15 per cent royalty on oil, a corporate tax of 20 per cent, and up to 70 per cent of its profit from the project to the Afghan government. The contract is valid for 25 years.

The practical work will start in October this year. CNPC will also pay rent for land used for its operations.

According to the mines ministry estimates, the deal is expected to bring in US$5 billion for the Afghan government over the next ten years. The Afgahn government is hoping that projects in the mining and oil sector will cut its reliance on imports from Iran and Central Asian countries.

CNPC had won the bid in early September last year after beating rival bids from Buccaneer Energy, Tethys Petroleum and Shahzad International.

Although the Amu Darya blocks are small compared to global standards, the deal would put CNPC in a better position to win bigger fields like the Tajik Basin, which is estimated to hold some 1.8 billion barrels of oil .

Kuwait Energy makes another discovery in Egypt KUWAIT ENERGY ANNOUNCED a new oil discovery in Egypt's Ahmad-1X well, located in the Gulf of Suez's Area A concession.

The newly discovered Ahmad-1X well was drilled to a depth of 2,110 meters. The initial test recorded a flow rate of 890 barrels of oil equivalent per day from the Kareem formation level.

Kuwait Energy Plc Deputy Chairman and Chief Executive Officer, Sara Akbar, said, "The Ahmad-1X well is located in a potentially rich area and we look forward to continuing testing and development activities in the area to reach its maximum potential. This is a further contribution to the productive capacity of the Egyptian energy sector and we are glad to play

30 Oil Review Middle East Issue One 2012

a part in this success.â&#x20AC;?

This discovery brings the total number of oil, gas and condensate discoveries made by Kuwait Energy in Egypt, since 2008, to 14 discoveries, three of which were made in Area A. Kuwait Energy is the operator of Area A and holds a 70 per cent working interest.

Omani independent Petrogas E&P holds the remaining 30 per cent interest.

Egyptian operations contribute the largest share to Kuwait Energyâ&#x20AC;&#x2122;s working interest production, comprising 17,700 barrels of oil equivalent by the end of 2011. Kuwait Energy is the operator of three blocks in Egypt, namely

the Area A, Burg El Arab development lease and the Abu Sennan concession. It also has interests in two other non-operated blocks: Mesaha concession and East Ras Qattara development lease.

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Drilling on Maha-1 well completed

Drilling contract awarded to Global Petrotech

TETHYS OIL ANNOUNCED that drilling of the Maha-1 exploration well on Block 3 onshore Oman has been completed but has been suspended to enable further studies in the future.

The well encountered oil, but the oil saturation was too low to be produced.

According to Tethys Oil, Maha-1 was drilled southwest of the producing Farha trend in an area not covered by 3D seismic. The vertical well was drilled to a total depth of 1,465 metres below sea level, encountering the Barik Sand at 1,409 metres. There were minor oil shows encountered while drilling the Barik. However, the oil saturation was too low to be produced and a subsequent sidetrack encountered even less saturation. The well has been suspended to enable further studies in the future.

"Oil is clearly present in the Maha part of Block 3. However, additional seismic will be required to mature leads to prospect in this area, "commented Tethys Managing Director Magnus Nordin.

The drilling programme on Block 3 continues with two rigs currently operating on wells FS-18 and FS-31 respectively. Both wells are located within the Farha trend 3D seismic area and are targeting as yet undrilled fault blocks.

Tethys has a 30 per cent interest in Blocks 3 and 4. Partners are Mitsui E&P Middle East B.V. with 20 per cent and the operator CC Energy Development S.A.L. (Oman branch) holding the remaining 50 per cent.

Test production from the Early Production System (EPS) on Blocks 3 and 4 onshore of Oman continues and amounted in December to 248,031 barrels of oil, corresponding to 8,001 barrels of oil per day (BOPD). Tethysâ&#x20AC;&#x2122; share of the production, before government take, amounts to 30 per cent of the total, or 74,409 barrels, Tethys Oil reported.

IRAN'S OIL MINISTRY awarded Global Petrotech Company a contract to drill two appraisal wells in the South Pars oil layer. The contract is valued at around US$182mn and was signed between Pars Oil and Gas Company and Global Petrotech Company in the presence of the Oil Minister Map of South Pars location Rostam Qasemi.

According to the contract, the Iranian company must drill two appraisal wells in 40 months to assess the South Pars field's oil exploitation potential.

The wells will also provide information on the amount of in-place oil reserves of the field and pave the way for the formulation of a major development plan for the offshore field.

A major feature of the project is six km of horizontal drilling in the South Pars field's oil layer aimed at gathering information and upgrading reservoir models of the joint oil field.

The development of the Iranian side of the oil layer had been constantly postponed. The new contract aims to produce a daily total of 35,000 barrels of crude oil from Section A of the field in the first phase of its development.

South Pars gas and oil field covers an area of 9,700 sqm, 3,700 sqm of which are in Iranian territorial waters and the remaining 6,000 sqm are in Qatari territorial waters.

Testing at Oman Block 15 restarts TESTING OPERATIONS ON Block 15 onshore Oman have restarted.

A jet pump has been installed in the JAS-2 well in an attempt to clear the well from water and enable it to flow hydrocarbons. The Block 15 license has been extended for three years, until October 2014.

The JAS -2 well, drilled in 2008, showed the same log response while drilling as the JAS-1 drilled in 2007. Whereas the JAS-1 well flowed reasonable quantities of gas and condensate, the JAS -2 well however, tested only water.

Subsequent analysis of JAS -2, including a comprehensive logging program in 2010, suggests that the water comes from a system

The Block 15 license has been extended to 2014

of fractures located at the far end of the 927 metres horizontal section. Indications are that the fracture system is limited with finite volumes of water.

The test now being conducted, will attempt to pump off the water and enable the well to flow hydrocarbons.

The Block 15 license has been extended until October 2014 with a minimum work programme consisting of among others additional seismic studies and the drilling of one more well.

Tethys has a 40 per cent interest of Block 15. Odin Energi A/S holds the remaining 60 per cent and is operator.

Gulf Keystone provides drilling programme update in Iraq GULF KEYSTONE GAVE an update on its ongoing exploration and appraisal programme in Iraqi Kurdistan.

Shaikan-4 Appraisal Well: The company continues a well testing programme for the Shaikan-4 appraisal well, drilled six km to the west of the Shaikan-1 well, targeting several formations in the Jurassic and Triassic. One well test in the Triassic has been completed and six further tests are planned.

Shaikan-5 Appraisal Well: The Shaikan-5 appraisal well is currently drilling at a measured depth of 1,008 meters. After slower than expected drilling progress due to

32 Oil Review Middle East Issue One 2012

temporary hole stability issues encountered in the shallow formations, the well is now drilling ahead to the estimated total depth of 3,500 meters subject to technical conditions.

Shaikan-6 Appraisal Well: The Shaikan-6 appraisal well has drilled to a measured depth of 362 meters and 26" casing has been set. The well will drill to the estimated TD of 3,800 meters subject to technical conditions.

Shaikan Extended Well Test: At the end of 2011, Shaikan test production levels were in excess of 4,000 barrels gross of oil per day and are due to increase further after the ongoing upgrade of the Shaikan-1 &

3 EWT facility has been completed and additional test production facilities have been designed and built.

Akri-Bijeel Block: According to the Operator's Akri-Bijeel block operational update and 2012 outlook, the exploration and appraisal programme will continue with two exploration wells (Barkman-1 and Gulak1) and four appraisal wells (Aqra-1, Bijell-2, Qalati-1 and Qandagul-1) to be drilled in 2012.

Following the completion of the Bekhme-1 exploration well testing programme the rig is moving to the Aqra-1 appraisal well drilling location.

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NPCC bags EPC contract in India INDIA'S OIL AND Natural Gas Corp (ONGC) has awarded National Petroleum Construction Company (NPCC) a US$150.6mn for the engineering, procurement and construction (EPC) of Platforms 14 and 16 in the Mumbai High Field.

The project includes the engineering, procurement of materials, manufacturing, transportation, installation and trial run for five offshore rigs, said a statement from NPCC. NPCC is targeting projects in Saudi Arabia as well as new markets farther afield such as Angola, Iraq, Kazakhstan and Southeast Asia, according to CEO Aqeel Madhi.

NPCC to provide EPC services for offshore rigs

Claims of higher oil extraction at Hengam Field MANAGING DIRECTOR OF the National Iranian Offshore Oil Company (NIOOC) says that Iran is currently extracting 2.5 times more oil from Hengam joint field compared to the neighboring Oman, reported Press TV. Mahmoud Zirakchian-zadeh said that Iran has been seriously pursuing tapping from the field in recent years and based on the current plans, extraction will increase during the current and upcoming years.

Iran is developing its part of the offshore Hengam oil field, shared with Oman, on its own.

Iran began tapping oil from the field about a year later than Oman, but is currently extracting about 22,000 bpd of extra light crude oil from the offshore field.

Oman teamed up with a British company three years ago to start tapping from the joint Hengam field, called Bukha in Oman, by building a 25km pipeline.

According to current estimates, Iran's oil extraction from the field will hit 30,000 bpd by March 2012.

The National Iranian Oil Company has invested US$450mn in the first phase of the field's development and a total of US$800mn has been allocated to the first and second phases of the field's development.

Hengam oil field is located about 45 km off Iran's Qeshm Island in the Persian Gulf and straddles the common sea border with Oman.

The field was discovered after oil was first drilled in 1975. The second well was drilled in 2006 and subsequent reservoir studies put the field's in-place oil and gas reserves at, respectively, more than 700 million barrels and about 2 trillion cubic feet.

Iran has the world's second largest gas reserves but has struggled for years to develop them due to tightening international sanctions that have kept foreign energy firms away.

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Gas

S07 ORME 1 2012 Gas_Layout 1 31/01/2012 14:46 Page 34

Qatar and Jordan discuss offshore gas terminal JORDAN AND QATAR ARE discussing the possibility of building a liquefied gas terminal at the Red Sea port of Aqaba at an estimated cost of about US$1 billion, according to officials.

Jordan currently imports 96 per cent of its energy needs, costing about 20 per cent of its gross domestic product. The Jordanian-Qatari talks on the proposed gas terminal project came amid Amman-Cairo discussions on the price of natural gas that Egypt supplies to the kingdom through a pipeline that runs through the Sinai.

Under the regime of ousted strongman Hosni Mubarak, Egypt offered favourable prices to Jordan.

However, the government in postMubarak Egypt has said it wants to renegotiate the agreement. Reports say that Cairo is asking for several times the favourable prices stipulated in a 2004 agreement.

Minister of Energy and Mineral Resources Khaled Touqan said a Qatari delegation held talks with Jordanian officials on the possibilities of Jordan importing liquefied gas from Qatar.

The talks focused on the proposal for setting up an offshore gas terminal at Aqaba to receive and distribute gas throughout Jordan, he said.

Jordan and Qatar have already jointly formed a technical committee to work out how Jordan could receive natural gas supplies from the Gulf exporter. Jordan's Minister of Energy and Natural Resources, Qutaybe AbuQura, told the kingdom's official Petra news agency last week that he had agreed with Qatar's Minister of Industry and Energy, Mohammad alSada, to form the task force, which will examine prospects for supplying Qatari LNG to Jordan via the port of Aqaba on Jordan's Red Sea coast.

First LNG carrier to Oman Drydock ONE OF THE biggest and most modern ship repair yards in the Middle East, Oman Drydock Company (ODC), has recently received its first LNG carrier, the Muscat LNG, owned by Oman Shipping Corporation SAOC. As part of its middle term service, Muscat LNG underwent the service operation at ODC during 11 days and was delivered within the estimated 12 days. The service The first LNG carrier arrives operation for Muscat LNG included the mechanical cleaning of the main boilers and the fire sides. She was pressure tested and the LNG Cargo pumps, the ballast pumps and the safety and mounting valves for the main boiler were

overhauled. The cable hangers and cables were renewed on flying passage (at five locations) and new cable supports (20 sets) for the cable way were installed during passage and the core wires were modified in tube type fluorescent light. As part of the regular maintenance work, the hull was equally painted. After the successful repair at ODC, the ship loaded LNG at Qalhat Terminal and left for the Far East. Since its soft launch in April 2011, ODC has been moving prudently towards a gradual ramp-up of its operations. Starting with handling of relatively small vessels, ODC has since then handled a total of 32 ships of varying sizes.

Qatargas to meet new emission limits GE OIL & Gas has signed a contract with Qatar Operating Company Limited (Qatargas) to supply advanced combustion technology that will reduce gas turbine emissions at the Qatargas 1 Utility complex to meet new regulations from the Qatari Ministry of Environment. The deal was announced

by GE at the 20th World Petroleum Congress that was held in Doha recently.

GE will provide Dry Low NOx (DLN) 1.0 combustion system designed to achieve low emissions levels of 25 parts per million (ppm) for nitrogen oxide. The technology will be used to upgrade six GE Frame 6B gas turbines that are providing the power for three onshore LNG trains at the Qatargas 1 site in Ras Laffan Industry City, 70 kilometers from Doha.

Qatargas, which pioneered the LNG industry in Qatar, today is the largest LNG producing company in the world, with a capacity of 42 million tons per year. Qatargas also is a trend-setter in environmental responsibility and was the first company in Qatar to establish an ambient air quality program, which helped to set the agenda for future controls on air emissions for all Ras Laffan industries.

“At the core of our environmental commitment is our objective to reduce emissions to the lowest practical levels,” said Alae Sadic Al Hassan, Qatargas’ Ventures Manager. “After evaluating a variety of solutions, we determined that GE’s DLN combustion system offered the optimum solution to achieve the required emission levels.

James Baldwin, Environmental Manager, Qatargas, added: “Qatargas is focused on reducing our emissions footprint and energy use to the lowest practical levels and aims to be a strong pacesetter within the LNG industry in this regard.”

The installation of GE’s DLN systems will begin this year, with the sixth and final unit completed by 2013. Equipment for the project will be provided from GE facilities worldwide, including Greenville in the US.

Iran may go it alone if Kuwait dithers IRAN SAID THAT it would launch full-scale unilateral development of the disputed offshore Arash gas field in the Gulf if Kuwait does not respond to its offer of joint development, according to the official Irna news agency.

"Our emphasis presently is on joint partnership strategy rather than competition, and we are hopeful to reach a conclusion with Kuwait over the development of the shared Arash field," the agency quoted Mahmoud Zirakchianzadeh, the head of state Offshore Oil Company, as saying.

He said Iran's policy on shared oil and gas

34 Oil Review Middle East Issue One 2012

fields is partnership rather than confrontation.

But "if Iran's positive diplomacy is turned down, we will be carrying on our efforts at Arash field unilaterally just as we did in Hengam oil field," Zirakchianzadeh said, using stronger language than Iran has used previously in the dispute. Iran is developing its part of the offshore Hengam oil field, shared with Oman, on its own. Zirakchianzadeh said Iran has already launched its "operational activities" on the development and production at Arash and was not dragging its feet in anticipation of Kuwait's response.

The Arash gas field is located on Iran-Kuwait's water border and it is called Dorra in the Kuwait part of the field.

S07 ORME 1 2012 Gas_Layout 1 31/01/2012 14:46 Page 35

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Gas

S07 ORME 1 2012 Gas_Layout 1 31/01/2012 14:46 Page 36

Iran confident about Caspian discovery

UK ‘dependent’ on gas from Qatar

THE HUGE GAS field, named Sardar Jangal, which has been recently discovered in Iran's territorial waters in the Caspian Sea, has the capacity to produce 880,000 barrels per day (bpd) of crude oil, MP Asadollah Abbasi told the Fars news agency.

Ali Osouli, managing director of Khazar Oil Company, announced in December 2011 that "the field holds an estimated eight billion barrels of crude oil." "An exploratory well has been drilled in the gas field to give new details on its hydrocarbon reserves," the Shana news agency quoted Osouli as saying.

The Sardar Jangal field holds at least 50 trillion cubic feet (some 1.4 trillion cubic meters) of gas reserves. The field, in waters 700 meters deep, lies wholly within Iran's territorial waters.

According to Oil Minister Rostam Qasemi, excluding Sardar Jangal, Iran has 11 trillion cubic meters of proven gas reserves in the Caspian Sea. Qasemi also announced that Iran is now the sole country in the region which has found access to the technology to drill wells in deep waters.

Meanwhile, gas production in South Pars (SP), Bushehr province will stand above 280mn cubic meters by the end of the current Iranian year, (March 20, 2012), said the managing director of Pars Oil and Gas Company.

Moussa Souri added 260mn cubic meters of gas per day are currently being extracted from 11 platforms of phases one to 10 of South Pars, IRNA reported.

He said the gas extracted from the sites is purified in SP's refineries after being transferred and is then injected into the nationwide gas networks.

THE UK’S DEPENDENCE on Qatari LNG has grown so stark that, last year, all but two cargoes of the product shipped into the UK came from Qatar. The situation is about to get worse, analysts say, raising profound questions over UK energy security. Not only is Iran threatening to cut off all Qatar's LNG exports by blocking the critical waterway, but even if that does not happen, the UK will The LNG shipments from Qatar are not guaranteed be unable to rely so heavily on Qatar in the coming years. Unlike other European nations, Britain has not guaranteed its LNG cargoes with long-term fixed contracts. Deutsche Bank calculates that only 24 per cent of the UK's LNG coming from Qatar is secured under fixed contracts, meaning the rest can be diverted to the highest international bidder. The Qatari gas the UK relies on has in part taken the place of more reliable gas from the UK's own North Sea, whose production is quickly declining because of the age of the fields and dwindling investment. In fact, Qatar's supply to the UK grew 67 per cent from 2010 to 2011, according to the Department of Energy and Climate Change.

Egyptian gas cuts cost Jordan billions ONGOING UNRELIABILITY OF Egypt gas supplies is forecast to cost Jordan over US$2 billion this year as energy officials struggle to meet the rising costs of electricity generation.

A report issued by the Electricity Regulatory Commission (ERC) projects the ongoing unreliability of Egyptian natural gas to cost Jordan an additional JD1.7 billion, some US$2.4 billion, by the end of 2012.

Egyptian gas supplies dipped from 220 million cubic feet per day in 2010 to an average of 80 million cubic feet in 2011, a

drop which cost the Kingdom an additional JD1 billion and pushed the annual national energy bill to a record high JD4 billion last year.

According to the ERC, the drop in gas supplies and increased reliance on costlier heavy fuel oil have pushed the costs for the National Electric Power Company (NEPCO) to sustain electricity generation to 156 fils per kilowatt hour, over three times the 52 fils per kilowatt hour rate the firm sells electricity to consumers.

"We are seeing generation costs rise each day and this is adding to our deficit," said Ghaleb Maabreh, NEPCO director.

Officials say the mounting deficit is placing "added pressure" on the Ministry of Energy to secure alternatives to an energy source that has been the target of both sabotage and diplomatic wrangling over the last 12 months.

"For too long we have relied on one energy source and now we are witnessing the negative consequences," Maabreh said.

Ras Laffan welcomes 1,000th LNG carrier A RECORD NUMBER of LNG tankers have loaded in the Year 2011 in Ras Laffan Port and on 28th December 2011, the RasGas vessel “Simaisma” became the 1,000th LNG (Liquefied Natural Gas) tanker to arrive in the Port. The RasGas chartered vessel built by the Korean Daewoo shipyard and delivered in 2006 is able to load an LNG cargo of 146,000 cubic meters. The vessel owned by a joint venture of Nakilat & Maran Gas Maritime, is on long term charter to RasGas. The 1,000th tanker bound for Europe was loaded simultaneously with the 999th, 1001th & 1002th LNG tankers and they in total took on board approximately just over half million cubic meters of LNG. To mark the occasion, a ceremony was held in Ras Laffan Port with senior representatives from RasGas, Qatargas, Nakilat and Qatar Petroleum. Ras Laffan Industrial City (RLC) Acting Director, Capt.

Feisal Saad presented a commemorative traditional Arabic dhow to the “Simaisma” ship master Capt. Apanomeritakis Georgios.

Speaking at the event, Capt. Saad said, “Just in June this year, the Port celebrated the 5,000th LNG loading since the start of operations in 1996.

36 Oil Review Middle East Issue One 2012

Celebrating the occasion, an award ceremony was held at Ras Laffan

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Petrochemicals

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Two reports look at the new growth agenda within the GCC petrochemical industry and highlight the development opportunity in this growing sector and what challenges lie ahead for GCC markets.

High growth potential for GCC

petrochemical market T

HE PETROCHEMICAL INDUSTRY faces a bright future in the GCC and two recent reports look at the reasons why there is a growth agenda in the region and the opportunities these developments can bring.

The first report, ‘Breaking New Ground in the Downstream Petrochemicals Sector,’ A.T. Kearney provides the analysis in a report compiled in collaboration with the Gulf Petrochemicals and Chemicals Association (GPCA).

The study looks at GCC petrochemical industry development opportunity and the next wave of growth in the sector.

The second report was released by AlixPartners and looks at the ‘Growth paradigm in GCC chemicals: strategic implications, project development and performance improvement.’

AlixPartners believes that “the Middle East will maintain the global hot spot for petrochemicals.”

A.T. Kearney in the study with GPCA stated: "With one of the highest population growth rates in the world, expanding downstream will not only contribute to the region’s overall GDP but will create fertile ground for the many job placements required for the younger population over the next decades."

The current production and diversification planned in the GCC petrochemical sector

Downstream Expansion Dr Jörg Fabri, a director in AlixPartners’ Dubai said, “Moving production further downstream could make sense for many GCC chemical companies, but only if some requirements are fulfilled. In particular, chemical companies in the region will need to improve operational efficiency.”

According to the analysis by A.T. Kearney compiled in collaboration with GPCA: “The GCC petrochemical sector has already taken significant steps toward moving downstream, expanding manufacturing capabilities of commodity materials.”

This expansion will see a wave of Green Field investments in the region. AlixPartners points out that Sabic is set to spend US$48.2 billion between 2011 and 2020.

Borouge will investment is at least US$3.2 billion in Borouge 3 and Aramco has already announced it will spend US$20 billion in its joint venture (JV) with Dow Chemical, Sadara.

While, Qatar Petroleum and Shell signed a deal at the end of 2011 to develop a Petrochemical complex in Qatar.

In Saudi Arabia the expansion will see more

38 Oil Review Middle East Issue One 2012

The Middle East will maintain the global hot spot for petrochemicals - AlixPartners

competition in the domestic petrochemical sector. “With Saudi Aramco becoming more competitive the Saudi market will no longer be dominated by one player, Sabic,” Fabri explained.

Feedstock AlixPartners stated that feedstock is key to cost competitiveness in petrochemicals and that C2 and C3 feedstock from GCC is the basement for local chemical production. With almost half of the global new capacity of some C2 based products will be built in the GCC. According to the analysis by A.T. Kearney compiled in collaboration with GPCA: “Competition to feedstock access is brewing.

The traditional feedstock, ethane, is ultimately limited in certain countries and may therefore not be a sustainable source to support the long-term

future growth of the petrochemical industry.

Capturing more value along downstream chains allows players to incorporate, economically more expensive, available feedstock such as those from gas condensates and naphtha.”

A.T. Kearney added: “the opportunities span multiple interrelated industries and sectors from advanced chemicals to plastics and rubber through to formulated chemicals.”

Using figures sourced from Deutsche Bank, AlixPartners found that chemicals companies in the Middle East have a cost advantage of as much as 90 per cent in ethane production over those in Europe or Asia, and up to 35 per cent in liquefied petroleum gas (LPG) production.

However, the cost advantage in producing naphtha is only up to 10 per cent to 15 per cent, depending on the transfer process used and logistics, meaning that changing market dynamics will exert additional competitive pressure on Middle East chemicals producers.

Clusters One key part of the petrochemical expansion will be growth of industrial clusters. According to AlixPartners, there are around 200 different industrial cluster initiatives in the GCC with those

S08 ORME 1 2012 Petrochemicals_Layout 1 31/01/2012 14:48 Page 39

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Petrochemicals

S08 ORME 1 2012 Petrochemicals_Layout 1 31/01/2012 14:48 Page 40

integrated chemical clusters in the GCC are required, however, synergy level is still far below BASF,” said AlixPartners.

Market access According to AlixPartners, the GCC is in particular well located to supply growth markets in Asia. The Middle East will be the main supplier to satisfy the fast growing demand from Asian markets.

It is vital that GCC chemical companies understand the trends in second and third markets of chemical client industries. AlixPartners argued that by “understanding trends in client industries secures GCC chemical companies to adopt development and production to the right direction and avoids “sunk” investments into declining market segments.”

The GCC petrochemical industry will see major expansion in the future

Outlook around chemicals are the most important ones.

A.T. Kearney highlighted these initiatives in its analysis compiled in collaboration with GPCA: “Championed by key GCC industry stakeholders, numerous initiatives have begun supporting downstream expansion. A common approach has been to build specific industrial areas, known as chemical poles and polymer parks, where downstream players can cluster together in a

favourable environment.”

“Industrial clusters are a great idea and are a great way to create synergies,’ AlixPartners said in its report.

Integration will become more and more important in the future but AlixPartners believes that the GCC is quite away from achieving full integration as BASF has done over the years.

“Thus master plans for the development of

A.T. Kearney concluded in the GPCA study that: “GCC petrochemical companies are strongly positioned to take the lead in downstream expansion. Existing global reach of GCC petrochemical players has embedded the industry with unique insight into trends and value chains of multiple segments, which can be leveraged to shape and support local development downstream.” n

Honghua Golden Coast Equipment FZE introduction Honghua Golden Coast Equipment FZE (Honghua Dubai), registered in Jebel Ali Free Zone in Nov of 2006, is one of the sole corporations of Honghua Group in China(listed in Hongkong stock market in 2008). The total area of the workshop for Honghua Dubai is about 21,000m2, including 2800m2 workshop (owning lathe, boring machine, milling machine, plate shearing machine, welding machine and other equipments), 500m2 warehouse and a 17,000m2 commissioning yard.

Honghua Dubai will be the assembly, maintenance, refurbishment, spare parts supply, equipment leasing, after sales service and marketing center of Honghua Group in Middle East and Africa. In addition, new technology and new products of Honghua Group will be displayed here.

40 Oil Review Middle East Issue One 2012

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S09 ORME 1 2012 Sabic_Layout 1 31/01/2012 14:55 Page 41

S09 ORME 1 2012 Sabic_Layout 1 31/01/2012 14:55 Page 42

SABIC Review

Despite the unpredictable global economic backdrop, Saudi Arabia’s downstream champion SABIC remains in bullish mood, says Martin Clark.

Going from strength

to strength S

AUDI BASIC INDUSTRIES Corporation (SABIC) is hoping to bolster its increasingly global reputation in 2012 but it faces key challenges in the year ahead, including anti dumping measures and potential feedstock issues. The Saudi downstream champion, 70 per cent owned by the Saudi government, is already one of the world’s top manufacturers and suppliers of chemicals, fertilisers, plastics and metals.

And it expects more of the same this year despite the bumpy conditions in troubled markets such as Europe. At the turn of the year, SABIC vice chairman Mohamed al-Mady said he was confident 2012 would be another positive year for the Middle East region’s petrochemical sector despite concerns over Europe slipping back into recession as a result of the ongoing euro debt crisis.

Al-Mady, who is also chairman and chief executive of the influential Gulf Petrochemicals and Chemicals Association (GPCA), believes that the Eurozone will experience modest growth this year, while the US will also avoid a double dip recession.

Strong footing “If this growth forecast prevails in 2012, it should be a good year for our industry,” he said. “Financial results should receive an additional boost due to improved industry operating rates in 2012 as there will be less new capacity coming on stream.”

Speaking at the sixth annual GPCA forum in Dubai

42 Oil Review Middle East Issue One 2012

on December 13, al-Mady highlighted the profitability enjoyed by most chemical producers during 2011.

While 2012 will no doubt throw up plenty of challenges - with mixed demand indicators also emanating from higher growth Asian markets such as China - SABIC has certainly entered the year on firm ground.

Another challenge facing the company is contesting any remaining anti dumping measures The company’s assets now amount to more than SR340 billion (US$91 billion) - up from SR317 billion (US$85 billion) in the last published annual accounts, for 2010 - while last October, SABIC posted record net profits for the third quarter of 2011. This is just the start, however, as the company expands into new and more complex production areas. Going forward, it aims to increase total production to a massive 130 million metric tons by 2020, making it a true giant in the world’s downstream industry. On the ground, SABIC finished last year in typically bullish style, with affiliate

Saudi Arabian Fertiliser Company (SAFCO) issuing a contract for the construction of the SAFCO-5 plant to Italian engineering group Saipem The SR 2 billion (US$533 million) plant will be one of the world’s largest urea plants, with an annual capacity of 1.1 million tons of urea. The facility is expected to start commercial production in the third quarter of 2014.

Recent initiatives Other flagship projects underway inside Saudi Arabia itself include the Al-Jubail Petrochemical Company (KEMYA) plant, a joint venture with ExxonMobil. Saudi Kayan, which is 35 per cent owned by Sabic and 20 per cent by Al-Kayan Company, is also building a speciality chemicals complex at Jubail, although it has been affected by delays.

Like all recent initiatives, the SAFCO-5 project forms part of SABIC’s long-term sustainability plans, with an aim to convert 850,000 million tons carbon dioxide (CO2), that is currently vented into the atmosphere, into urea, a valuable fertiliser. SAFCO intends to to apply for a Clean Development Mechanism (CDM) certification to gain financial credits for the emission cuts. The project’s economies of scale will also contribute to reducing the intensities of energy consumption by eight per cent and water consumption by 11 per cent, both precious and scarce resources. The new

S09 ORME 1 2012 Sabic_Layout 1 31/01/2012 14:55 Page 43

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SAFCO-5 facility fits with SABIC’s drive to reduce its overall environment footprint, says al-Mady, also SAFCO chairman. He challenged the wider petrochemical industry to provide more sustainable solutions as it increases its scale and capacity.

SABIC benefits from a fairly diversified feedstock and product mix

Sustainability “The Gulf petrochemical suppliers must possess the most material and energy efficient processes and we must produce products that enable the entire value chain to be more sustainable,” he said.

Key measures include the GPCA establishing the Responsible Care initiative in the Middle East and Gulf region, an attempt to address key sustainability issues, and to build a link with peer associations around the world.

Tough tests But there are, no doubt, tough tests coming too, both for SABIC and other Saudi and Middle Eastern downstream producers. Management will be watching key demand indicators closely, especially those from China. Some 50 per cent of SABIC's sales go to global emerging markets, with 30-40 per cent to China alone, making it arguably the group’s single most important overseas territory.

Another challenge facing the company is contesting any remaining anti dumping measures, which have been enacted in some overseas markets as global economic growth has withered through the past year. India imposed a 6.5 per cent duty in November 2010 on polypropylene imports from SABIC and a few other producers, saying the suppliers sold their products below cost. While India has now withdrawn such measures, Saudi officials still started this year locked in talks with Turkey, where SABIC is accused of dumping mono ethylene glycol. As of mid-January, the Turkish claim was the only such case outstanding remaining against the company.

Cost advantage A similar anti dumping case in China dating back to 2010 has also since been scrapped.

The accusations arise largely from Saudi Arabia selling gas at greatly subsidised rates to local downstream product manufacturers, including SABIC. Riyadh has set a gas price of US$0.75 a

Like all recent initiatives, the SAFCO-5 project forms part of SABIC’s long-term sustainability plans million British thermal units, NCB Capital, the investment arm of Saudi Arabia’s largest bank by assets, said in a December report, one of the lowest prices anywhere in the world. This price was set in 1998 when the average price of crude oil was a mere US$13 per barrel; the average price of oil is now in excess of US$100 per barrel.

By contrast, US natural gas prices averaged US$4.028 a million BTU last year. With its integrated production flow, feedstock cost advantage and wide production base, SABIC is therefore able to post globally leading margins, as it has repeatedly done so in recent years.

But the prospect of higher gas prices may be a far greater challenge to SABIC long-term, than short-term anti dumping battles. Saudi

downstream producers are now facing difficulty gaining new allocations of ethane at the current subsidised price for capacity expansion plans, due to rising domestic gas needs.

Global demand Although SABIC benefits from a fairly diversified feedstock and product mix, NCB Capital believes ethane costs still account for seven per cent of the group’s total production cost for the petrochemical segment. The company’s efforts to extend growth opportunities outside Saudi Arabia have already diluted some of this natural cost advantage, although this has been a necessary step in deepening its involvement in new territories such as China.

This strategy has placed SABIC at the heart of the world’s petrochemicals industry, however, a move that will stand it in good stead in the years ahead, whatever the economic headwinds bring, or any potential future shifts in gas pricing. With global demand red light indicators flashing, it means SABIC remains as well placed as any downstream player in the Middle East and beyond in 2012. n

Investing in the best TECHNOLOGY REMAINS INTEGRAL to all that SABIC does, as it extends its global footprint far and wide. The company is now among the world’s market leaders in the production of polyethylene, polypropylene and advanced thermoplastics, glycols, methanol, and fertilisers – and one of the largest producers of steel in the Middle East. It now has 18 international tech centres, manned by 1,500 scientists and researchers. These facilities have enabled the company to amass around 7,000 patents. At the end of last year, SABIC even set up a new venture capital arm, SABIC

44 Oil Review Middle East Issue One 2012

Ventures, based in the Netherlands, to invest in new and innovative technologies and businesses. The venture capital firm will target new technologies primarily in the USA, Europe and Asia. Among the company’s more recent investments, SABIC Innovative Plastics opened a new facility at its Mt. Vernon site in the USA - a hub for major innovation breakthroughs and the source of some 500 patents - to facilitate chemistry and process development for the high performance polymers product line. The new site will enable SABIC to more rapidly produce new

polymers, particularly custom formulations, for its customers. The intention is also to increase customer access to SABIC research scientists and product development specialists.

“It takes us to a new level of high performance polymers technical innovation and dedicated support that our customers expect of us, especially those in growing, high-demand sectors like aerospace and healthcare,” said Sanjay Mishra, global high-performance polymers technology leader, specialty and performance, SABIC Innovative Plastics.

S09 ORME 1 2012 Sabic_Layout 1 31/01/2012 14:55 Page 45

SABIC Review

S09 ORME 1 2012 Sabic_Layout 1 31/01/2012 14:55 Page 46

Sustainability a key driver - Al-Ohali MR MOSAED AL-OHALI, Executive Vice President, Manufacturing, Sabic spoke to Oil Review about Sabicâ&#x20AC;&#x2122;s sustainability drive and ambition to become innovation leaders. Al-Ohali was one of the plenary speakers at MEPEC in Bahrain. Al-Ohali expanded on the main themes of his speech, saying: â&#x20AC;&#x153;My speech was a reflection of our realisation at Sabic. What are the focus areas for us? Sustainability is coming to be a very important subject for us going forward. It is becoming a very important theme. Our approach will not be legal compliance but instead we aim to embrace sustainability as a way to create value for us.â&#x20AC;? He added that some people think sustainability means investments in energy optimisation and investment in Co2 reduction â&#x20AC;&#x201C; from a certain perspective, this is true. That is the cost side of it. â&#x20AC;&#x153;What we are looking at is the value side of it.

Because as we spend capital, we gain business benefits far in excess of our sustainability costs. So as we drive more sustainability, we aim to gain market leadership, we are not compromising our economic viability we still want projects that are economically viable on their own but also achieving our sustainability goals.â&#x20AC;?

Al-Ohali went on to discuss the importance of innovation which, â&#x20AC;&#x153;we firmly believe that we can

Al Ohali (centre) pictured at the MEPC event in Bahrain

not meet our corporate objectives by just being a smart follower as has served us very well in the past. But going forward, we need to be technology innovator and we need to be a recognized innovation leader. We do not want to innovate in everything, but we want to have innovation leadership in our core business.â&#x20AC;?

This does not mean that in the future Sabic will not enter into joint ventures, far from it. â&#x20AC;&#x153;We still have a lot of room for a lot of partners and there are many things we can do together,â&#x20AC;? observed Al-Ohali.

Training is very important to Sabic. As Al-Ohali explained: â&#x20AC;&#x153;Knowledge sharing is very important for us. We have a number of initiatives on training ongoing, both in-house and with third parties. We are trying to move from formal kind of training into training that is competence based. We are engaged in a big project where we are mapping out the competency needed for all our career paths and then what we do in terms of training and development, work experience that we want to give to our professionals to achieve the competencies prescribed for the career path they choose.â&#x20AC;?

Al-Ohali believes this provides a very comprehensive, total approach to training and development.

Al-Ohali talked about his positive outlook for the downstream industry. â&#x20AC;&#x153;In terms of building technical capabilities I think we are definitely in the right place and on the right track. We are moving to be more efficient and, in a way, we are optimising our costs. So from that aspect we are doing the right thing in terms of organisational structures and in terms of selecting the types of technologies we want to use. Now this is only on the manufacturing capabilities side. Al-Ohali did add that to succeed Sabic will need other things, such as a favourable market.

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SABIC PLANS TO take advantage of gaps left in the German market by dominant local BASF SE (BAS) by offering customers a fuller range of plastics and chemicals.

Sabic is marketing itself as a one-stop shop for makers of materials used in goods from cars to medical-gear, Konrad Hellmann, head of the Riyadh-based company’s German operation, said in an interview. Sales volumes in Europe’s biggest economy increased about 10 per cent last year.

The Saudi company bought General Electric Co. (GE)’s plastics unit in 2007 and is building up its polymers operation. By contrast, BASF sold its Basell plastics venture in 2005 and shifted styrene operations into a venture last year. Sabic has an opportunity to battle rivals in Germany that can’t supply a full array of plastics, Hellmann said.

“Most global companies don’t want 100 suppliers, instead they want just one supplier that can provide a wide range of products,” Hellmann said. “We can offer the customer everything from a high-performance polymer down to polyethylene and everything in between. Only a few others can do that.”

Sabic, which runs its European operations from Sittard in the Netherlands, in September A wider range appointed country leaders across Europe to

coordinate polymer, thermoplastic and chemical sales. Customers of one business unit are being introduced to products from other units, Hellmann said.

“At the big companies, the original equipment manufacturers, the decisions on which plastics should be used in a product are made in Germany,” Hellmann said. “It’s an advantage when you have a big portfolio and a solution for every materials problem.”

Sabic, which was founded in 1976 to find a use for flare gas burned off during oil extraction, recently reported Q4 profit that missed analysts’ estimates. As well as Germany, Chief Executive Officer Mohamed AlMady is driving expansion in the faster-growing markets of Asia and Latin America, he said.

Growth may come from acquisitions, as well as internal investment and innovations, Hellmann said. Sabic, which is 70 per cent state owned, looks at potential targets that come on the market and wants to expand in specialty chemicals, he said. Sabic bought Huntsman Corp. (HUN)’s U.K. polymer and chemical units in 2006 for US$810mn, adding plants that make ethylene and polyethylene plastics as well as benzene-related chemicals for the European market. A year later it followed with the purchase of GE’s plastics unit for US$11.6 billion, gaining operations in the U.S., Asia and Europe.

Oil Review Middle East Issue One 2012 47

SABIC Review

SABIC seeks to widen sales in Germany

PetroRabigh Review

S10 ORME 1 2012 Petro Rabigh_Layout 1 31/01/2012 14:58 Page 48

Rabigh Refining and Petrochemical (Petro Rabigh), the large joint venture Saudi petrochemical company, has an critical year ahead with a vital decision on the important phase two expansion yet to be finalised

Key role in Saudi’s

petrochemical drive P

ETRORABIGH WAS SET up in September 2005 and is a leading joint venture petrochemical company based in Saudi Arabia run by Saudi Aramco and Sumitomo Chemical of Japan.

Sumitomo Chemical is a founding shareholder with ownership of 37.5 per cent along with Saudi Aramco who are also founding shareholders owning 37.5 per cent as well; the remaining 25 per cent is owned by the general public and is traded on the Saudi Stock Exchange (TADAWUL).

Petro Rabigh is one of the largest fully integrated oil refinery and petrochemical production facilities in the region and it is the largest integrated refinery in the World built in a single stage.

The company has the highest component of inward FDI in the Kingdom and it started operations at its US$10.1 billion complex in 2009.

Platts have ranked the company among the world’s fastest growing energy companies and in its annual Top 250 Global Energy Company Rankings, PetroRabigh 167.5 per cent compound growth rate (CGR) gave it second place in the top 50 improved companies as it jumped from 228th to 75th in the overall rankings.

PetroRabigh experienced a frustrating 2011 which saw long bouts of maintenance works hinder refining capacity levels which had a direct impact on seeing the company post lower end of year, fourth quarter results.

The petrochemical firm is actively looking at the option of issuing new stocks to help fund expansion of the complex which revolves around Rabigh II which was supposed to have been finalised between Aramco and Sumitomo by the year end but did not meet that deadline.

Leading complex The world beating PetroRabigh complex is comprised of 23 plants that produce 18.4mn tonnes per annum (mpta) of petroleum-based products and 2.4 mpta of ethylene and propylene- based derivatives.

Its facility includes a 400,000 barrel per day refinery, a 700,000 tonnes a year polypropylene plant, a 600,000 tonnes a year linear low density polyethylene unit, and a 200,000 tonnes year propylene oxide facility. This accounts for about 19 per cent of Saudi Arabia's total refining capacity.

This refinery was upgraded to include a high olefin fluid catalytic cracking unit (HOFCC) for converting heavy and light oils to gasoline and other distillates, which added new annual capacities of 2.8mn tonnes of gasoline and 900,000 tonnes of

48 Oil Review Middle East Issue One 2012

The PetroRabigh complex started in 2009

The complex is comprised of 23 plants that produce 18.4 mpta of petroleum-based products and 2.4 mpta of ethylene and propylenebased derivatives propylene, a feedstock for petrochemical products.

It produces 1.3mn tonnes of ethylene a year as primary feedstock to produce a variety of refined petroleum products and petrochemical products.

The refinery has mainly been producing eight million tonnes of heavy oil, 5.3mn tonnes of light oil, three million tonne of naphtha and 2.6mn tonnes of kerosene annually.

The company’s product portfolio includes refined products comprising liquefied petroleum gas, naphtha, gasoline, gas oil, fuel oil, and kerosene.

It also offers polymer products comprising LLDPE, HDPE, homopolymer polypropylene, and impact copolymer polypropylene products; and monomer products consisting of propylene oxide and mono ethylene glycol products.

The refinery caters mainly to the Saudi, European and North African markets. But the company is looking at focusing on the fast-growing markets of China and India in the future.

Q4 2011 results PetroRabigh’s fourth-quarter saw a 4.4 per cent drop in net profit which was due in large to lower refining margins.

The company made a net profit of US$13.4mn in the three months ending Dec. 31, compared with US$14mn during the same period a year earlier.

The reason for the decrease in net profit during the fourth quarter of 2011 versus the same period of the previous year is due to low refining margins during the fourth quarter of 2011. The reason for achieving net profit during the fourth quarter of 2011 versus a loss for the previous quarter of the same year is due to the extension of the periodical maintenance (T&I) throughout the previous quarter, which resulted in low production volumes.

Rabigh II The ambitious phase two expansion includes a new aromatics facility and a number of value-added derivatives. The Rabigh II project is due to be completed in the first quarter of 2015.

The project involves expanding the 1.3mn tonnes/year cracker by 300,000 tonnes/year, thanks to an additional 30mn scf/day ethane allocation from Saudi Aramco. The aromatics complex, based on 3mn tonnes/year of naphtha, will house a paraxylene (PX) plant of 800,000850,000 tonnes/year and a benzene unit with a capacity of 200,000-400,000 tonnes/year.

S10 ORME 1 2012 Petro Rabigh_Layout 1 31/01/2012 14:58 Page 49

Utilities to: Power Industrial Muncipal

Meticulous & Presistant The Reward Total Customer Satisfaction

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PetroRabigh Review

S10 ORME 1 2012 Petro Rabigh_Layout 1 31/01/2012 14:58 Page 50

originally scheduled completion date of the third quarter 2010.

Operational milestone

A petrochemical plant

In addition, a third party will establish a new manufacturing facility at the Rabigh site for a purified terephthatic acid (PTA) unit that produces 500,000700,000 tonnes/year and a polyethylene terephtalate (PET) unit that produces 200,000400,000 tonnes/year, the report said.

With the expansions, Petro Rabigh would be able to produce 2.5mn tonnes/year of ethylene and propylene-based derivatives.

The venture received engineering and construction bids for the project last year and was set to award work contracts this year.Construction tenders for seven packages were issued and bidding was due to close on 1 October. But this did not happen and the final investment decision is now meant to be made by the end of 2011.

The main talking at the end of last year revolved

around Aramco and Sumitomo missing their yearend target for deciding whether to invest US$6 billion to US$8 billion to enlarge the facility.

Aramco stated that it was going to meet with Sumitomo Chemical at the start of 2012 to discuss “where to go from here” on the planned expansion.

“When we said year-end, we meant more or less that date,” Khalid Al-Falih, President and CEO of Saudi Aramco, said.

Saudi Aramco is committed to make the expansion of Phase Two of PetroRabigh happen and al-Falih said he’s confident that both companies will come to an agreement on the enlargement.

Sumitomo spokesman Hironori Mizushima said in December that the company was still conducting a feasibility study on the project. The study was delayed due to financial constraints from its

PetroRabigh did have some good news to shout out about at the end of 2011 when the company reached a significant operational and financial milestone at midnight on Dec. 31 with the successful completion of the Lenders Reliability Test (LRT) in all plants at its refining and petrochemical complex.

Successful completion of the LRT, which requires that no single stoppage should exceed 72 hours, saw the complex operate for 210 days with average feedstock consumption at over 90 per cent of design and average production at over 80 per cent.

PetroRabigh was able to vastly exceed minimum requirements by maintaining an operating factor of 97 per cent for the tenure of the LRT. The safe and successful LRT marks the completion of the physical testing of the PetroRabigh Complex and means that it is now fully operational and optimised.

2012 PetroRabigh’s Phase Two expansion programme and higher product prices are prime growth drivers for the company. But plant shutdowns last year and the failure to finalise the investment package for the Phase Two expansion remain concerns. n

AES Arabia provides special treatment for oil, gas & petrochemical industries More recently, the company has focused on the AES ARABIA’S MANAGER International Sales, Mr oil, gas and petrochemical markets – mainly Asad Iqbal Khan spoke to Oil Review Middle on supplying water filtration to power plants and the company’s development and recent refineries where the chemical content of even achievements. relatively clean water can have destructive AES Arabia Ltd is a subsidiary of American effects on a plant’s systems. AES’s clients in this Engineering Services Inc., based in Tampa, field include Saudi Aramco, Petroleum Florida. This Middle Eastern division arrived in Development Oman, Total, the Saudi Basic Saudi Arabia in 1993 and sought an expansion Industries Corporation, Khafji Joint Operation that could follow local trends and operate (KJO), Technip, JGC, Petrofac, Samsung independently from its parent company in the Engineering, SK Engineering and many more.

US. “We are cooperating with them in their process “When we saw potential in the area we industries and even for exploration,” says Mr established our independent office here in Khan, who adds that the company provides the Riyadh to capture Middle Eastern and North industry with water desalination equipment and African markets,” explains Mr Khan. wastewater treatment, whether sanitary or AES provides design and fabrication of industrial Mr Asad Iqbal Khan, process. water and waste water treatment systems as AES Arabia’s Manager-International Sales When it comes to its customers, AES views its well as specialist chemicals for reverse osmosis, strongest attribute to be the after-sales service that it provides. Mr Khan wastewater treatment and cooling systems. The company has since outlines: “We are involved with oil and gas companies and we have grown to focus more on the oil, gas and petrochemical markets. It has specialists from a chemical background who contact our clients been growing consistently and in 2008, to sustain its development, AES regularly.” moved into a new regional headquarters in Riyadh. This 3,000 square The workforce itself is mostly homegrown, as Mr Khan confirms: metre complex was set up to accompany AES’s 18,000 square metre “There is enough in-house capability. We have almost 300 people and production and warehousing facility. The company also maintains branch most of them are indigenous.” Much of AES’s employee development offices in Jeddah and Khobah and has been awarded ISO 9000:2008 is also administered in-house, seeking outside help only when accreditation along with the ASME certification. absolutely required.

While the company’s operations centre around Saudi Arabia, its business AES Arabia has dedicated Quality Assurance/Quality Control and Safety activities and reputation are widespread throughout the GCC & MENA department that focuses on maintaining high standards throughout the region, with representation in key areas such as Abu Dhabi, Dubai, facility, from inspection of the materials and components, to the Bahrain, Kuwait, Qatar, Algeria etc through its business partners. In finished treatment plants.

Algeria, for example, it was provided an order by Japan Gas Corporation.

50 Oil Review Middle East Issue One 2012

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Saudi Safety & Security

S11 ORME 1 2012 Saudi S&S_Layout 1 31/01/2012 14:59 Page 52

The second SSS exhibition and conference will focus on the protection of industrial, other commercial, residential and infrastructural assets.

Meeting the needs of

hazardous industries S

AUDI SAFETY & SECURITY (SSS 2012) will open its doors in Dhahran from 4th-6th March, bringing a wide range of specialised products including fire detection, suppression and protection equipment to the Kingdom's most concentrated region of energy and industrial infrastructure.

All events will be taking place under the patronage of the Governor of Eastern Province and the KSA Dept of Civil Defence will again be providing full support.

The exhibition itself – there were 40 clients for last year's inaugural event, which attracted more than 1500 visitors in all – will feature the following three business themes, including large-format equipment outside where appropriate: Safety products and services – to protect the Kingdom's ongoing multi-billion public construction programme and ensure the safety of all workers massive investment is needed in HSE equipment and training.

Current standards have recently been independently described by international comparison as “mediocre but improving”. Assessing risks, managing them and raising standards in construction procedures and adherence to the building code are specific targets in what is easily the Middle East's largest single market for items like machinery guards other accident-prevention equipment.

Expenditure increases Security – like all other energy states undergoing a substantial expansion and privatisation programme in both its utility and industrial sectors, the Kingdom now faces a range of internal and external threats, which is already resulting in pro-active expenditure increases of up to 10 per cent annually.

All sectors of the economy are affected. Total procurement of commercial security equipment and services such as intruder detection equipment between 2011-2014 is estimated to be of the order of US$10 billion or more.

Fire – the Kingdom's massive building programme – housing, industrial facilities, education and healthcare facilities, together with all forms of necessary supportive infrastructure – is resulting in a rapid increase in demand for fire detection and prevention installations, and the capital equipment needed to fight this ever-present threat. A wide range of items like sprinkler systems will be on display as well as the capital equipment needed to fight a large-scale outbreak.

As the Kingdom's leading exhibition of safety, security and fire equipment SSS 2012 will provide a splendid opportunity to see all these and the commercial services that support them under one roof.

Commented a representative of exhibitors Satel Co last year: “A good venue to meet clients as well as competitors and understand new technologies coming to the market.”

By general consent the inaugural SSS conference last year was both timely and a resounding success, meeting the need for an event in the busy Eastern Province that encourages discussions about civilian security, safety and fire prevention/fighting issues with acknowledged industry experts from far and wide, including crucially the Civil Defence authorities.

Wisely it was local infrastructure protection issues that were concentrated on by the select group of 75 who attended the 2011 event, most of them nationals of the GCC states and many representing other

52 Oil Review Middle East Issue One 2012

www.sss-arabia.com

local interested parties like the National Guard, the Red Crescent Authority and the King Abdulaziz Port Authority.

Afterwards Alan Chen, a VP of China's Sinopec (a national oil company with wide international interests), commented on an “Opportunity to learn about the latest information in the field of safety and security as well as to network and exchange business-related information.”

Key presenters Local NOC representative Engineer Hamed Rashed al-Rashed of Saudi Aramco referred favourably on his feedback report to “A good chance to explore many new innovative solutions to new challenges.”

And the HSE Manager at Group Five Pipe Saudi made a key point about keeping abreast of changes in the rules – both local and international.

Rodello Rimando said “It was valuable to keep up to date with the existing safety standards and regulations in the Kingdom.”

This observation has been picked up in planning this year's follow-up programme with the insertion of a special introductory session on “Understanding changing security regulations, new security threats and how they impact on your business” fronted jointly by the Higher Commission for Industrial Security and the Saline Water Conversion Co. Recent changes in safety requirements will be covered in a separate session, too.

S11 ORME 1 2012 Saudi S&S_Layout 1 31/01/2012 14:59 Page 53

Saudi Safety & Security

S11 ORME 1 2012 Saudi S&S_Layout 1 31/01/2012 14:59 Page 54

Key presenters this year will include at least three senior executives from Saudi Aramco, representatives of the local downstream and utilities industries, the Saudi railway organisation and the Al-Khodari Group (construction).

By general consent the inaugural SSS conference last year was both timely and a resounding success Technologies The conference opening ceremonies take place on 4th March with a keynote speech on securing Saudi's industrial infrastructure, and a following discussion on assessing the evolving challenges facing local S&S professionals. The “Changing regulations” session will lead into a review of technologies in what organisers BME Global call “The security space”, such as centralised remote monitoring, protecting Saudi Aramco's investments and ROI in this field generally, and the increasing use of “smart” technologies such as maintaining cyber security.

The first day, devoted to Security issues, will conclude with twin sessions on optimising strategy (audits, planning and prevention rather than response strategies) and improving the security of industrial facilities (in the construction phase, identifying hazards and through use of smart ID cards).

Day two issues come under the Safety Focus heading, starting with how to encourage the compliance of employees, improving national “safety culture” (especially in construction), and the ever-present issue of ensuring contractor and direct-employee safety levels match up. The special challenges of ensuring safety standards in the simultaneous construction of the Kingdom's multiple Industrial Cities – one of the world's largest ongoing projects - will be looked at.

The special needs of hazardous local industries like petrochemicals will be covered on the same morning, with special emphasis on building safety culture and management planning to take account of change in general.

The first-half sessions of this specifically Safety day will focus on the very specific needs of planning fire safety design and equipment for protection of all new buildings, and the special hazards arising from transportation, of both supplies and products.

Transport issues will be followed up after lunch too, with specific attention to accident prevention, securing facilities against piracy, and countering other maritime threats.

A series of pre-conference training workshops are being offered on 4th March covering off-the-job safety programmes, developing a behavioural safety culture, technology selection, and security auditing. ■

For more information visit www.sss-arabia.com or call +966 (3) 859 1888 (Exhibition Centre) or +44 203 328 6526 (Conference). All events are being sponsored by leading Gulf fire equipment manufacturer NAFFCO.

Safety in the oil and gas sector is vitally important

54 Oil Review Middle East Issue One 2012

S12 ORME 1 2012 Innovations_Layout 1 31/01/2012 15:10 Page 55

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KOG 2012

S12 ORME 1 2012 Innovations_Layout 1 31/01/2012 15:10 Page 56

KOG 2012 to focus on collaboration and innovation THE KUWAIT OIL and Gas (KOG) Summit & Exhibition 2012 runs over three days and runs from February 12th-15th at the Exhibition Hall at the Regency Hotel. The event is being hosted by KPC and being organised by the CWC Group Limited.

The 2011 event was a huge success with the inaugural event seeing over 500 participants from over 120 different organisations attending across the entire value chain.

The organisers, CWC, have announced a raft of new activities for KOG 2012.

The main new addition is the introduction of Technical Seminars at the Exhibition. These will be showcasing the cutting edge technology being developed in Kuwait’s energy industry.

Summit KOG 2012 will once again host a premier forum for doing oil and gas business in Kuwait. The summit will explore the opportunities and challenges of Kuwait oil and gas in a global context, focusing on sharing knowledge and discussing new technologies and best practices.

The programme will address the critical issues and discuss the strategies for future development and prospects for future ETSA agreements, regional cooperation in energy security and the opportunities in Kuwait’s downstream market.

The 2012 summit will also see new panels which will be an interactive panel discussion focused on Regional Cooperation and one focused on Environmental Sustainability.

www.cwckuwait.com/

Exhibition The Exhibition at KOG 2012 will provide a cost-effective platform for companies to showcase technologies, products and services. With 1000sqm of exhibition space available and free visitor passes for trade professionals, the exhibition is an ideal way to expand business in the oil and gas sector in Kuwait.

Networking Networking is at the heart of the event, including an evening reception and a gala dinner on February 12th. Participants will benefit from the opportunity to meet face-to-face with the new Kuwaiti and international stakeholders and engage in real dialogue with key decision makers, government officials and industry experts to drive their business interests.

The First Stainless Steel Welded Pipe Mill in the Middle East Outokumpu Armetal Stainless Pipe Company (OASP) is the leading manufacturer of high quality EFW (Electric Fusion Welding) stainless pipe with diameters range from ½” to 8”, Sch10s & Sch40s; Grade 304L, 316L& Duplex. OASP pipes are suitable for a wide range of industries, such as, Oil & Gas, Petrochemical, Desalination, water treatment and general construction.

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56 Oil Review Middle East Issue One 2012

S12 ORME 1 2012 Innovations_Layout 1 31/01/2012 15:10 Page 57

WHEN YOUR MISSION IS MAKING MEDICINES THAT SAVE LIVES, FAILURE’S NOT AN OPTION. ESPECIALLY POWER FAILURE. Tests are performed, results compiled and production lines roll.

Every day, a leading U.S. pharmaceuticals innovator makes the products that treat serious and life-threatening medical conditions.

Loss of power for even a short time could cost a production run … and hope for those who need help now. For the health of this company and its customers, KOHLER backup power solutions are the best medicine. With KOHLER, the power stays on because the people behind the products are on. Always.

You can’t make breakthroughs in medicine if you’ve got breakdowns in power. Which is why so many people trust KOHLER to come through. Without fail.

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SPE is what you need.

Upcoming Middle East Events Register now for these upcoming SPE events and meet with other professionals to learn about and discuss the latest E&P technical advancements:

SPE North Africa Technical Conference and Exhibition (NATC) 20–22 February 2012 InterContinental Citystars Cairo, Egypt

North Africa Technical Conference and Exhibition

SPE Oil and Gas India Conference and Exhibition

20–22 February 2012 Cairo, Egypt

28–30 March 2012 Mumbai, India SPE Oil and Gas India Conference and Exhibition

www.spe.org/events/natc

Managing Hydrocarbon Resources in a Changing Environment

www.spe.org/events/ogic

28–30 March 2012 Mumbai, India

Society of Petroleum Engineers

Society of Petroleum Engineers

www.spe.org/events/natc

SPE EOR Conference at Oil and Gas West Asia

Middle East Health, Safety, Security and Environment Conference and Exhibition Society of Petroleum Engineers

SPE Middle East Health, Safety, Security and Environment Conference and Exhibition (MEHSSE)

Sustaining World Energy through an Integrated HSSE and Business Approach

www.spe.org/events/mehsse

Paper Proposal Deadline is 15 August 2011

2–4 April 2012 Beach Rotana Hotel, Abu Dhabi, UAE

2–4 April 2012 Abu Dhabi, UAE

SPE EOR Conference 16–18 April 2012 Golden Tulip Hotel Muscat, Sultanate of Oman

EOR: Building Towards Sustainable Growth

www.spe.org/events/mehsse

16–18 April 2012 Muscat, Oman

In Association with OGWA Exhibition

www.spe.org/events/ogwa

Supported by: Titanium Sponsor:

OGWA Organiser:

Ministry of Oil and Gas Sultanate of Oman

Society of Petroleum Engineers

www spe org/events/mehsse

www.spe.org/events/ogwa

For information about other SPE events in this region visit www.spe.org/middleeast.

Exhibit space and sponsorship opportunities are available.

For information visit the conference websites.

S12 ORME 1 2012 Innovations_Layout 1 31/01/2012 15:10 Page 59

Mobile drilling waste recycling

ANTECH LIMITED, HAS significantly expanded its Wellhead Outlet range. In addition, the entire range is now fully IECEx-certified. Since 2001, AnTech has been supplying ATEX-certified, single and dual conductor Wellhead Outlets. The company announced two new options: the triple conductor and the fibre optic line. The Wellhead Outlet is used in permanent completions where pressure and temperature must be continuously monitored. It connects the downhole cable to the surface telemetry system, and is attached to the wellhead to provide a safe connection between the cables and seal against downhole pressure.

The configuration ensures that the integrity of the wellhead is maintained, even if the downhole cable is flooded.

BAKER HUGHESâ&#x20AC;&#x2122; ECO-CENTRE CR, a mobile and portable onshore waste facility, offers operators a one-stop solution to processing a wide range of drilling fluids and solids in close proximity to shale formations. This eliminates the need to take waste to separate facilities while reducing environmental impacts and transportation risks. This new processing center, which has been used in the Marcellus Shale, is modular in design and uses the best available technology to deliver a 100 per cent reusable, recycled fluid. The system works by destabilizing the fluid, the solids then are brought together and separated out using a centrifuge that allows for maximum return of the solids-free liquid to the fluid system. â&#x20AC;&#x153;Operators are facing water shortages and increased restrictions on raw water use and disposal in many areas of the world. Our portable Eco-Centre CR can be located where operators need it, reducing costs and efficiently recycling drilling waste for future use,â&#x20AC;? says Scott Schmidt, Baker Hughesâ&#x20AC;&#x2122; President of Drilling and Evaluation. â&#x20AC;&#x153;This mobile facility allows operators to process a greater variety of drilling waste streams with a higher throughput, while reducing the impact on the environment.â&#x20AC;? The Eco-Centre CR centralized recycling waste management service offers the best available technology to: 6 Reduce the amount of water pulled into the waste stream, avoiding unnecessary trips to stream or well.

6 Lower the cost of transporting fluids and drilling waste based on central location.

6 Decrease the amount of waste that has to be sent to disposal. All recycled water can be reused in other operations.

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Oil Review Middle East Issue One 2012 59

Innovations

Expanded wellhead outlet range

Innovations

S12 ORME 1 2012 Innovations_Layout 1 31/01/2012 15:10 Page 60

Shell opts for Parker Hannifin

Delivering oil production increases

PARKER HANNIFIN CORPORATION has signed an Enterprise Framework Agreement (EFA) with Shell as a single source supplier for the provision of instrumentation valves, manifolds, process-to-instrument valves, fittings, tubing, protective enclosures and related products. Under the terms of Shell's EFA - which runs for an initial period of five years – Parker's Instrumentation Group will supply Shell and its affiliates worldwide with a broad range of process instrumentation products.

"We are delighted to win this contract with such a major player in the oil and gas business, and are confident that our manufacturing resources on three continents and our global Parker Sales Company support network will meet the enormous challenges of this supply agreement," says Ian Huggins, General Manager of Parker Hannifin's Instrumentation Products Division in Europe.

"We see this agreement marking the start of a sustained period of progress in instrumentation technology,” adds Sheldon Banks, EMEA Sales and Marketing Manager of Parker Hannifin Instrumentation Products Division in Europe. “We believe that such a cooperative relationship between major players in their respective spheres will help to establish many new standards for performance, safety and cost reduction."

Over the last decade, Parker has invested heavily in innovation, and has made many significant advances in areas including safety, speed of installation and maintenance, and lowering emissions. In particular, Parker's new products can dramatically reduce the number of potential leak paths in a fluid flow system, and improve ergonomics for instrumentation and maintenance engineers.

CAMCON OIL’S APOLLO digital intelligent artificial lift solution can deliver as much as 1,000 BOPD (Barrels of Oil per Day) more oil production from a typical well and, in one scenario, a 110 per cent increase in production compared to traditional gas lift equipment. These were the findings of a recent report by production technology consultants, Laing Engineering Training Services (LETS), who evaluated a number of different gas lift solutions at various stages of the productive www.camcon-oil.com lifecycle based on a typical subsea well scenario. The report found that APOLLO, part of Camcon’s Digital Intelligent Artificial Lift (DIAL) solutions, led to increased production rates and offered much greater flexibility than conventional gas lift equipment based on wireline retrievable valves and side pocket mandrels. This was due to the APOLLO’s ability to set real-time injection rates in response to changing reservoir conditions over the life of the well.When assessing the APOLLO units under a number of life cycle well scenarios – from one day to three years – APOLLO’s ability to move injection depth up and down the well in response to changes in well production chracteristics, such as reservoir pressure and water cut, was clearly seen to yield increased production with, at times, incremental production of over 1,000 BOPD.

Increased power for offshore applications

Raising the bar in well intervention

CATERPILLAR ANNOUNCED THE release of the new Cat® C28016 generator set with 10 per cent increased power. The C280-16 60 Hz generator set is now available at 5359 ekW, 900 rpm and features numerous electronic upgrades.

This increased power provides industry-leading power density www.catoilandgasinfo.com while maintaining its proven reliability and durability for offshore environments. This new rating joins the already existing C280 product line that is rated from 1820 to 5200 ekW at 900 and 1000 rpm and is available in 6, 8, 12, and 16 cylinder configurations.

The C280 engine family meets EPA Marine Tier 2 and IMO Tier II emissions and is ideally suited for semi-submersible rigs, offshore supply and service vessels, drillships, and pipelayers.

“Our engines have a proven track record for reliability and durability in the harsh offshore environments,” said Antti Ekqvist, Caterpillar International Business Development Manager, Offshore Oil and Gas. “With the C280 generator set, we’ve taken 20 years of proven component reliability and combined it with our offshore expertise to create an engine and support network that the industry can rely on.”

The C280-16 features several key electronic upgrades to provide simplified rig and vessel integration and improve user ability for the operator. The C28016 integrates the next generation package monitoring system which allows the data from multiple generator sets to be monitored through the overall rig or vessel control system. The display panel is Marine Classification Society (MCS) approved, with a color display that allows complete customizable screens and alarm settings. The generator sets also feature dual ADEM™ A4 electronic control systems, which provide redundancy to maximize uptime and reliability. The ADEM A4 also provides tighter control over key parameters for cleaner, more efficient operation; simplified diagnostics and troubleshooting, and expanded monitoring capabilities.

THE WORLD’S FIRST high pressure (HP) retrievable bridge plug capable of withstanding a differential pressure of 15,000psi was unveiled by high-technology well intervention specialist Interwell.

Interwell developed the ultra slim, 2.2” OD, HP bridge plug to provide a reliable barrier in extremely high pressure conditions.

The ISO 14310 qualified tool contains an innovative packer back-up design which both compresses and constrains the element, reducing the risk of extrusion in extreme conditions and enables its operation to 15,000psi.

“We have established a new standard with this tool as we are the only company in the industry to develop a plug which can withstand such high pressures and is fully retrievable after use,” says Interwell’s UK managing director, Andrew Louden.

“This tool is a significant development in terms of its global applicability in ultra-deepwater environments, and from our perspective is a further major design and engineering achievement in a portfolio which already includes the highestexpansion ultra-slim bridge plugs available.”

The ultra-slim design of the patented element back-up segments of the HP plug reduces the risk of deployment and retrieval through narrow wellbore restrictions, a crucial operational benefit in high pressure high temperature (HPHT) wells.

Efficiency is further enhanced by each plug taking just one run to set and one to retrieve, providing a reliable and cost effective solution for well interventions.

Jim Laidlaw, business development director at Interwell Aberdeen, says: “Intervening in deepwater and HPHT wells is very demanding. Our key design aim was to develop the slimmest HP plug solutions in the market whilst also minimising operational complexity in these challenging well conditions.

Interwell has offices in Saudi Arabia, Abu Dhabi and Oman, in addition to its operations in Norway and the UK.”

60 Oil Review Middle East Issue One 2012

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GLOBAL JOINT INTEGRITY and engineering services company Hydratight has formed a strategic partnership with one of the world’s leading commercial diver training schools.

Hydratight and the UK-based Professional Diving Academy will collaborate on specialist courses aimed at improving both subsea joint integrity and skills, as well as diver safety.

The partnership aims to fill a gap in the current training provision for industrial divers,initially offering a course on the subsea use of bolting tools with extensive underwater practical tuition – the only course of its kind in the world.

L-R Hydratight's global competency leader Jason Barnard and PDA's training manager Neil MacMillan

AGR secures well management deal AGR CONFIRMED IT has been awarded a frame agreement which includes the possibility for total well management services with Statoil worth approximately 100-130mn NOK per year (US$17-21mn per year) .The contract period is for two years with the possibility for an additional two plus two years extensions.

AGR is the world’s largest independent well management organisation and is one of two service providers awarded this type of contract from Statoil. The primary scope of the contract includes the possibility of executing, planning, operations and post well activity for drilling and well operations out of Stavanger, Stjørdal and the northern areas in Norway. The frame agreement also includes well management support to Statoil's international operations where AGR also can provide support from its international offices including Aberdeen, London, Houston, Perth and Dubai/Abu Dhabi.

“This is a very encouraging start to the year, responds Executive Vice President in AGR Sjur Talstad. We are looking forward to supporting Statoil in their drilling and well operations in a time with increased drilling activity for the industry. Our well management teams are exceptionally experienced when it comes to this type of activity, ensuring our clients achieve enhanced operational performance within a safe environment.

Sjur Talstad, AGR’s Executive Vice President, commented: “We are known for operating within very challenging environments across the globe where we provide an innovative and effective approach to our clients. We look forward to supporting Statoil throughout the course of this contract. He adds that this contract will also result in strengthening of our organisations in Stavanger, Oslo and Trondheim.”

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Oil Review Middle East Issue One 2012 61

Innovations

Hydratight forms strategic partnership

Innovations

S12 ORME 1 2012 Innovations_Layout 1 31/01/2012 15:10 Page 62

Innovative Inova S. MOHARIR, SALES Director EAME & ISC, of Inova, recently spoke to Oil Review Middle East about the company’s growth plans for the region and its latest offerings of land seismic products.

Inova was formed in March 2010 as a joint venture company between ION Geophysical and BGP. Moharir explained: “We have acquired the best of both companies and both companies land seismic equipment have basically become part of Inova. We have a huge range of expertise and products on offer in all segments of the land seismic acquisition business” Inova sees the digital market as one of their biggest growth markets, especially here in the Middle East as having big growth potential.

“Inova is striving to be technology innovators: we already have a name in digital technology and we intend to push this aspect,” stated Moharir.

He pointed out that Inova are the leaders of digital technology in the industry and we were the first to come out with our digital sensor, VectorSeis, which is the leading digital sensor in the market.”

In Q4 of last year Inova launched five new products which meant that the quarter “was the most important phase so far in our growth strategy,” Mr Moharir said.

Moharir argued that the launching of five new land seismic products was quite an achievement and it “gives us a new impetus for new customers and that is really the main drive.” He also hinted that Inova was continuously developing its product portfolio and a new innovative product, specifically targeted for the Middle East region would be the next focus point for Inova.

The new products are targeted for all markets with some products aimed at existing customers and others targeting new customers.

Inova launched two new types of cable technology, one was an

Make sure you visit our new website with updated news coverage in the Middle East and North Africa.

www.inovageo.com

enhancement on an existing system, the redesigned FireFly DR31 and they also brought out a completely new autonomous node system called the Hawk SN11 recording system, which is based on a wireless platform.

Inova also came out with a new digital sensor, VectorSeis ML21, which is an enhancement to our main product and involves a 17 per cent reduction on power consumption as compared to the previous model.

To help promote these new products in the region Inova held a technical forum in Dubai early December last year for key customers– which introduced all the new products. It was Inova’s first technical forum and Moharir expects it will be the start of an annual event Henalso sees the Middle East as a very good market and expects strong demand for seismic products.

“We see a growing demand for our products in the Middle East and some of the recent trends which are coming out of the region point to this growth. We expect to see real growth in this sector in Saudi Arabia.”

Inova is active in most Middle East countries and the company expects growth in the Saudi and Omani market. But it is in the Iraqi market that Moharir expects to see the biggest demand.

“Iraq is major target area for us and it is turning out to one of our biggest markets. We are focused in both Southern Iraq and Iraqi Kurdistan. We have our systems working in Iraq and we have one of the largest crews near Basra using an Inova product. Iraq is a real focus point and we have eight projects coming up this year,” he concluded.

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62 Oil Review Middle East Issue One 2012

MICROTEST AG SPECIALISES in the measurement of internal diameters. Through permanent optimisation, constant further development and improvement, its measuring instruments have reached a high standard of precision, reliability and universality for the requirements of its customers. MICROTEST® highprecision mechanics are refined with high-tech electronics. As a result of intensive development it has now been possible to implement a digital module that enables even higher accuracies to be achieved than with analogue equipment. The measurement shaft, supported in two sets of ball bearings, carries a highly accurate sensor that generates 10,000 increments per rotation. The recording of values measured in 100nm steps improves the accuracy significantly.

The housing is manufactured from a glass fiber reinforced plastic and is fitted with cooling water-resistant seals at all entry points. The module meets the IP 67 standard of protection, is impact resistant, and can also withstand complete immersion in a swarf trough.

S13 ORME 1 2012 Technical Focus 01_Layout 1 31/01/2012 15:15 Page 63

Technical Focus

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ESPs used in a non-traditional role helped profile production in a carbonate oilfield to unlock higher reservoir potential, by Mubarak A Dhufairi, Saudi Aramco, and Paul Docherty, Schlumberger.

Reliability key to long-term

objectivity test A

COMPLEX CARBONATE OILFIELD in Saudi Arabia required pressure support to sustain production. Saudi Aramco was looking to achieve sustained production using the best-in-class reservoir management practices. The natural drive mechanism came from an aquifer screened from the overlying reservoir by a semi-impermeable tar mat, the geometry of which was relatively unknown, although it was thought to be continuous.

Even so, it was suspected that the tar mat might not be completely sealing. Accordingly, any enhanced oil recovery (EOR) plan using traditional water injection would not be effective.

This article describes a comprehensive, longterm injectivity test whose objective was to characterize reservoir sweep patterns so the optimum number and location of injectors could be determined.

of the injection scheme, in addition to qualifying the injection wells placement strategy. Therefore, to obtain supportable results, a massive test was envisioned involving some 3mn bbl of injected water over a 200-day period. Reliability, resolution and accuracy of the downhole gauges were absolutely essential because it was predicted that changes due to injection water could be quite subtle, particularly on the most remote wells in the

observation pattern. At the same time, reliability of the injection setup and equipment was equally important. Any breakdowns could completely mask the data transients the engineers were trying to measure.

Design anticipates tough conditions With such reservoir conditions, proper placement of injection wells relative to producing wells was of paramount concern to

A comprehensive test methodology was planned

Well placement was critical The initial approach to avoiding the tar mat issue was to geosteer horizontal injector wells so they landed just above the tar mat, in the transition zone between the heavy and light oil.

Geologist and reservoir engineers were faced with the challenge of placing the injectors optimally, so injection water would drive crude oil to the producing wells, leaving no movable oil residuals behind.

Before the entire reservoir pressure support scheme was committed, two pilot tests were designed involving a single injector well and six producers located at varying distances and directions. The six producers were intended to be utilized for observation and to monitor the rate of pressure build up with time for each. The producers/observation wells were equipped with downhole permanent and/or retrievable, high-accuracy, long-lasting, battery-powered electronic gauges. It was decided to perform a long-term injectivity (LTI) test with the objective of mapping the sweep pattern and effectiveness

64 Oil Review Middle East Issue One 2012

Figure 1: Pilot test well layout includes distance and direction from injection well to observation wells along with observed pressure increase over the test interval. [SOURCE: OTC 21130, Figure 3]

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Technical Focus

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Figure 2: Injection wellhead pressure (red) and injection rate (blue) are plotted as a function of time. [SOURCE: OTC 21130, Figure 4]

deliver production targets with the highest sweep efficiency model. Robust dual memory electronic gauges capable of withstanding sustained high temperatures for at least 31 weeks were specified. The observation wells were equipped with electronic gauges to monitor reservoir pressure response during the LTI test to confirm reservoir lateral connectivity and possible vertical communication between reservoir layers.

In an effort to aid the overall reservoir

At the same time, reliability of the injection setup and equipment was equally important

characterization, the injection well water profile was planned to identify the contributing zones across the horizontal section and map out the crossflow areas. Furthermore, plans were put to record an II/fall off test, which would be analyzed and compared to several pressure transient measurements recorded in several appraisal wells drilled during the project planning period. These measurements served to identify the fluid profiles in those wells along with any anomalies such as crossflow between reservoir levels that might skew pilot test results. The fact that the pilot test was conducted in a dynamic field environment meant that each pressure disturbance had to be accounted for so the final analysis would truly

66 Oil Review Middle East Issue One 2012

represent the interaction of the pilot test model of a single injector with six observation wells and no outside effects.

A comprehensive test methodology was planned. Pre-and post-injection measurements would be taken that would include both injection and fall-off tests. Thorough transient analyses were planned including: 6 Crossplots of differential pressure vs. logarithmic Horner time 6 Crossplots of differential pressures and the square root of time 6 Crossplots of logarithmic differential pressure and the log of time 6 Crossplots of the log of the pressure deriva-

tive and the log of time derivative.

Using derivatives is a traditional technique because the derivative is directly represented by one term of the diffusivity equation, the governing equation for models of transient pressure behavior in well test analysis.

Injection wellbore conditioning A complicating challenge lay in attempting to return injectors to their original status. During drilling, several of the injection wells experienced lost circulation into natural fractures in the carbonate sequences. These were mitigated by pumping viscous pills of hydroxyethylcellulose (HEC) polymers. As a

Figure 3: Test schematic illustrates redundancy and integration of reliable ESPs at the seawater intake and at the wellhead HPS [SOURCE: OTC 21130, Figure 1]

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Technical Focus

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result, many, if not most, permeable zones had high skin damage. To clean up the damage and restore the original skin effect, acid treatments were pumped. To maintain control over the test data, pre- and post-treatment injectivity tests were run. The skin mitigation program was not without its challenges. Deployed into the lateral using coiled tubing pulled by a downhole tractor, the tools became clogged with lost circulation material. A solution was implemented involving bullheading 300 bbl of solvent to dissolve the material that was affecting the control assembly of the tractor.

The post-treatment injection measurements, made using downhole gauges deployed on slickline, consisted of pumping 20,000 bbl of treated seawater into the formations; then pausing to conduct a pressure fall-off test. The fall-off test, which took 96 hours, provided vital information regarding the parameters of the injection scheme. Near-wellbore skin, interwell average reservoir pressure and permeability were determined.

Injection well performance was assessed using Hall-effect plots, based on injection volume and surface injection pressures.

Surface facilities designed for reliability To avoid further complications, considerable forethought was built-in to the surface system.

Basically the plan was to use treated seawater, pumped through a 1.9 mile (3 km) 6-in. diameter pipeline. At the injection well site,

two, 2-micron, Vortisand™ sand filters were deployed plus a chemical injection module before the water was pumped into eight, 500 bbl skid-mounted holding tanks. The tanks supplied a set of electrically powered triplex charge pumps providing input to the horizontal above-ground ESP pumping system (HPS). The pumps were energized using a Schlumberger variable speed drive (VSD) powered by three 500 kVA generator sets.

At the intake, duplex diesel-powered pumps drew seawater from a shallow seaside location.

These proved to be unreliable and were replaced by duplex submerged ESPs supplied by a motor generator. To assure the LTI test as a reliable source of injection water, the ESPs were determined to be the best solution. The original diesel pumps were retained onsite as backup. System design capacity was 20,000 bbl/day. At the wellhead, the HPS delivered 10,000 bbl/day of filtered, treated seawater at up to 2,500 psi.

During the design and construction of the surface facility, several important lessons were learned: 6 Ensure pump intakes were deep, clean and clear of sand and debris 6 Ensure pump is not deadheaded into a closed valve 6 Address careful alignment of shafts 6 Provide a compressor to facilitate system maintenance 6 Install tank supports to keep bottom valves accessible

6 Use duplex pumps to provide system integrity and backup

6 Provide concrete bases for rotating equipment

6 Install a subsurface safety valve to block H2S flowback from well

6 Perform full review of generators and VSDs for compatibility

Injectivity tests reduce uncertainties, save money The pilot injectivity tests were successful.

Dynamic data, including pressure transient analysis removed several faults from the geological model. At least 13 injector wells were dropped from the field development plan, largely because uncertainties about the tar mat sealing were redefined. System design issues were successfully resolved to address test goals and result in almost 96 per cent uptime.

It was determined that lower powered water injector pumps were required because the injectivity index turned out to be better than expected, and ESPs proved more reliable than diesel-powered pumps. Schlumberger pressure gauge systems and permanent downhole monitors proved both rugged and reliable over the 31-week test period in a hot and highly corrosive environment.

Importantly, data integration with other sources such as drilling data, field production history, available geology and petrophysical analysis from well logs all helped to mitigate risks of skewed interpretation. ■

Figure 4: The use of modular equipment facilitated transportation and setup in the desert and added flexibility to the system design as items were substituted to improve reliability. [SOURCE: OTC 21130, Figure 2]

Schlumberger and Petrofac to address new market opportunities PETROFAC AND SCHLUMBERGER announced that their Integrated Energy Services (IES) and Schlumberger Production Management (SPM) divisions respectively have signed a Co-operation Agreement under which these divisions will establish a working relationship to deliver integrated and high-value production projects in the emerging and growing production services and production enhancement market.

Schlumberger and Petrofac have complementary skill sets and execution capabilities. Both have built these through subsurface knowledge, facilities expertise and operational experience in integrated asset management with IES having particular strengths in facilities, engineering and O&M and project management while SPM has particular strengths in subsurface knowledge, production engineering, well construction, and project and asset management.

68 Oil Review Middle East Issue One 2012

Both companies will deploy their own capital in these production enhancement projects and neither company will seek to book reserves or production. The market opportunity for the collaboration is significant as major resource holders seek to develop discovered low-risk reserves against an industry environment characterized by a shortage of capability and capacity.

Miguel Galuccio, president of Schlumberger Production Management, said: “Schlumberger’s subsurface knowledge, production engineering, well construction and project management services coupled with Petrofac’s surface facility design, installation and ongoing operational field management create a life-of-field approach coupled with a performance-focused commercial model to optimize asset development and overall value.”

S14 ORME 1 2012 Technical Focus 02_Layout 1 31/01/2012 15:19 Page 69

By Enzo Dellesite, General Manager, T.D. Williamson Middle East FZE

saving time and money T

HE PROSPECT OF working on a pressurized piping system is daunting.

Pipeline operators are acutely aware of the risks involved, knowing that they must take the utmost care to ensure that the line is effectively isolated before work of any kind can take place.

The safe operation of every piping system demands ongoing maintenance, repair and, at times, intervention in order to modify the line for tie-in to a new addition to the network. To complicate matters, piping systems exist in every conceivable environment: from deepwater sea beds and remote mountain valleys to congested urban areas. Those responsible for their continued operation are keen to employ methods that will safely isolate the line in order that work can proceed, efficiently and cost-effectively. This is compounded by the fact that they are expected to achieve this without interrupting service.

Fortunately, isolation technology continues to evolve, bringing good news to operators of piping systems, both offshore and onshore. Safe isolation of systems found in hydrocarbon processing facilities, such as refineries, poses a unique challenge. Refineries, which typically require a large staff to operate and are by definition highly volatile environments, require a double block and bleed to safely isolate a pressurized line. Today’s refinery operators prefer this method because it allows them 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 of the line’s pressurized contents.

The STOPPLE Train plugging system is the only system that links two plugging heads to form a “train” that provides a double block and bleed function STOPPLE Train plugging system = reduced costs, improved safety To provide operators with a faster, more costeffective way to create a double block and bleed with minimal intrusions to the line, T.D. Williamson, Inc. (TDW) has developed the patent-pending

TDW hot tap & plugging site through fittings welded on pipeline

STOPPLE Train plugging system. The system relies upon TDW’s field-proven plugging technology to temporarily block sections of active piping systems.

The STOPPLE Train plugging system is the only system that links two plugging heads to form a “train” that provides a double block and bleed function. Traditionally, other methods have been

used to achieve double block and bleed, including the use of two separate valves with a bleed port between them. Other common approaches involve combining a valve and a plugging head with a port between them, a plugging head and an isolation plug with a port between them, or two plugging heads and a bleed port. Each method employs the

Oil Review Middle East Issue One 2012 69

Technical Focus

Innovative technology facilitates double block,

Technical Focus

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TDW operation completed. Fitting for hot tap operation is closed with the flange. Pipeline isolated.

dual barrier concept. Regardless of what is used as a barrier - valves, plugging head seals or a combination of these - the second barrier acts as a failsafe for the first.

The STOPPLE Train plugging system has been successfully used to create double block and bleed isolations for operators around the world One hot tap and fitting provides benefit of two in-line plugs “What sets the STOPPLE Train plugging system apart is that while traditional methods require more than one hot tap and fitting to achieve double block and bleed, the STOPPLE Train system requires only one,” said Laurent Fabry, Director - Line Intervention & Flow Assurance for TDW. The linked plugging heads are inserted into the line through just one opening. As a result, a single hot tap and fitting provides the benefit of a double block that has, until now, been achieved with two in-line plugs. By positioning the pressure bleed port between the two plugging heads, a void is created between the heads that allows the line to be bled down. This produces a zone of “zero energy.”

An added bonus is that the pressure bleed port also makes it possible to verify and monitor the

70 Oil Review Middle East Issue One 2012

primary seal. When TDW engineers set out to design a system that would offer improved double block functionality, it was critical that the system not only be safe; the system had to be failsafe. By using the tap between the two seals, the area can be continually monitored for leakage prior to – and during – work being carried out on the pipeline downstream. If, for any reason, the primary seal were to leak, the secondary seal will hold the line pressure. The secondary plugging head provides double block features at pressures to 1,480 psi.

Reliable in low and high pressure environments Because piping systems operate in low and high pressure environments, the STOPPLE Train system is designed to be extremely robust. Tests illustrate that when operating at low pressures, compression between the pipe internal diameter (ID) and the sealing elements creates an extremely effective barrier. At 0.5 psi to 5 psi, the compression fit alone is sufficient, meaning that the sealing element need not be energized in order to seal.

However, after the seal is energized, it will remain securely intact until it is broken by an external force; for example, by retracting the plugging head.

With regard to higher pressure environments, each plugging head in the system is rated to 1,480 psi at 180°F. The plugging heads have been successfully pressure-tested with a safety factor together, as well as independently.

Costs reduced, safety enhanced With just one hot tap and one standard fitting required to use the STOPPLE Train method, the risk

of potential leak paths remaining on the piping after work is finished is greatly reduced. This represents a dramatic improvement over traditional double block and bleed methods, which normally require double the number of line penetrations to achieve. Costs associated with the purchase and welding of fittings are reduced by 50 per cent, due to the fact that only one set is required. Further savings are realized by customers because less excavation is necessary, which reduces the overall time required to complete the job. Shorter jobs also translate to improved safety: the less time that personnel spend performing the job, the less likely they are to be exposed to potential hazards.

On-site, the need to provide physical site support, such as cranes and scaffolding, is reduced, as are the number of permits and inspections required.

For refineries, where space is minimal, the fact that fewer fittings are required means that there is more space in the pipe rack. This is particularly relevant, given that the STOPPLE Train plugging system performs properly, whether positioned horizontally or vertically. It can be operated, regardless of the pipe rack configuration.

Line isolated, costs reduced at Italian refinery Initially launched in North America, the STOPPLE Train plugging system has been successfully used to create double block and bleed isolations for operators around the world. Recently, TDW performed its first double block and bleed isolation with the STOPPLE Train plugging system in Europe.

The operation, which took place at a refinery in Italy’s Po Valley, illustrates how the method

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Technical Focus

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facilitates scheduled line maintenance. In preparation for planned line maintenance, TDW was retained to ensure that a key hydrogen sulphur line could be cut, plugged and safely isolated without shutting it down. The only other alternative would have been to shut the line and production unit down, resulting in a complete halt in production, which was deemed unacceptable.

Currently, TDW is in active negotiations with operators to carry out a number of STOPPLE Train intervention operations in 2012 With equipment from the company’s base in Nivelles, Belgium, a team of TDW technicians from Italy, Belgium and the United States used a standard 660 tapping machine to hot tap the line, and inserted one six-inch STOPPLE Train doubleblock and bleed plugging system to plug the line.

The operation was successfully completed in just one day, creating a secure environment in which critical maintenance and servicing could be carried out. The fact that the line was isolated with a minimum amount of equipment and required only one fitting meant that costs associated with welding and fittings were significantly reduced.

“The fact that the company’s first ever STOPPLE Train plugging system intervention operation in Europe went so smoothly, and that the customer benefitted in terms of enhanced safety and reduced

costs is extremely heartening,” said Georges Andrei, Hydrocarbon Process Industry Sales Manager Europe for T.D. Williamson SA. “The ability to create a safer working environment, reduce the time required to complete the job, and cut costs bodes well for operators everywhere.”

Preparing for valve change-out in Illinois, USA Further afield in Illinois, USA, TDW completed an isolation operation using the STOPPLE Train plugging system on a 10-inch diesel transmission pipeline that typically transports 1200 barrels per hour.

6 The isolation was necessary in order to prepare for safe and speedy replacement of an isolation valve on the line. After hydrotesting the equipment, TDW performed three downstream taps: one 2-inch equalization tap, one 10-inch tap for installing the STOPPLE Train plugging heads, and one half-inch tap for the purpose of bleeding the isolated section.

After removing the tapping machine, TDW mounted the STOPPLE Train system and connected the equalization and hydraulic hoses. The team then stopped product flow and closed two valves located approximately ½-mile north of the work area. A single bleed port was then opened between the two valves, providing double block and bleed on the upstream side of the work area. The STOPPLE Train plugging heads were inserted, the isolated section drained and the bleed valve opened to provide double block and bleed on the downstream side of the work area. The isolation valve scheduled for replacement was removed and replaced with the new valve. The upstream valves were then opened and the line pressure equalized before removing the STOPPLE Train plugging heads. The plugging heads were then fully retracted, the housing removed and a completion plug set in the fitting.

The entire process required just two days to complete. As a result, the customer was extremely pleased, particularly with the efficiency of the process.

Such was the case when TDW was called in to assist another customer near Lafayette, Louisiana.

This customer needed to add a new isolation valve and replace part of an existing 8-inch natural gas liquids (NGL) pipeline. To facilitate this, TDW used two STOPPLE Train systems - placed upstream and downstream - to isolate a 1.3 mile section of the pipeline. The customer used pipeline batching pigs to replace the NGL with nitrogen through the section of the line to be replaced. The pigs were launched at intervals to create a 1,000-foot buffer zone of nitrogen on each side of the work area.

First, the downstream STOPPLE Train plugging heads were set, followed by the upstream plugging heads. The customer then depressurized and bled down the 1.3 miles of nitrogen from the pipeline.

After verifying that no product had leaked past the secondary seals of the STOPPLE Train plugging heads, the bleed valves were opened to ensure that a proper primary seal had been achieved. Following these critical verifications, the line was deemed safe to cut and open. Each end of the pipeline was cut within approximately six feet of each STOPPLE Train plugging head. The customer then tied in the new line and installed an 8-inch block valve 50 feet downstream from the plugging heads located upstream. After completing these modifications, the customer closed the new block valve, and TDW proceeded to equalize between each of the STOPPLE Train systems and the valve. Both systems were retracted and each completion plug was set.

The customer was so impressed with the quality and efficiency of the operation, the company ordered two STOPPLE fittings to serve as part of its emergency response preparedness program.

Multiple applications

As these examples illustrate, the STOPPLE Train plugging system has been used successfully for operators seeking to carry out a broad range of applications. Enhanced safety and reduced costs are just two benefits that customers have realized when this innovative approach to piping system isolation has been used to prepare for scheduled maintenance, emergency repair work or tying in a new line.

Line tie-in goes “The success of these and many other double to plan in Louisiana block and bleed isolations achieved with the When operators prepare to tie-in a STOPPLE Train plugging system is paving the way new line to one that is for further use of this technology,” said Fabry. “This operating, they must ensure is especially important as TDW moves forward with that the live section of the plans to carry out operations on behalf of pipeline, piping system is properly refinery and petrochemical plant operators isolated before work can throughout Europe, Africa and the Middle East.” proceed.

Building upon its impressive track record in the United States—where TDW has carried out STOPPLE Train plugging system operations TDW STOPPLE Train Cutaway for nearly every major operator—the company is poised to dramatically expand this service.

Currently, TDW is in active negotiations with operators to carry out a number of STOPPLE Train intervention operations in 2012. ■

72 Oil Review Middle East Issue One 2012

S14 ORME 1 2012 Technical Focus 02_Layout 1 31/01/2012 15:19 Page 73

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S15 ORME 1 2012 Technical Focus 03_Layout 1 31/01/2012 15:22 Page 74

The Bourbon Gulf Star 3

Technical Focus

Thereâ&#x20AC;&#x2122;s a smarter way to work using marine access.

Offshore access bridges

the gap T

HE EVER INCREASING demand for oil and gas reserves from fast-growth economies in regions such as Asia, coupled with the technological advancements being leveraged by many companies has seen an increase in the number of operators developing resources in increasingly challenging environments such as the deepwater offshore.

Meanwhile, production from many existing fields is in decline, with a greater number of marginal prospects being exploited as a result.

These challenging resources often require greater investment; in research and development, personnel and exploration and production costs.

This means that more than ever, operators and service companies alike must come up with new ways of working to improve operational efficiency and reduce costs in other areas, while maintaining high levels of safety.

More than 10mn crew transfers take place annually across the world in the offshore oil and gas sector, either by helicopter, vessel, crane and basket, making it one of the highest cost activities in the industry. With the addition of a high risk factor, personnel transfer is an area that often comes under scrutiny.

Suitable vessel Operators rightly demand that transfer methods being used are inherently safe, proven, reliable and capable of handling the changeable conditions that

74 Oil Review Middle East Issue One 2012

occur in the offshore environment. Suppliers therefore, must provide solutions that are both technically and economically feasible.

Recognising all of these factors, market leader

There are further opportunities to explore in the development of marine personnel transfer Offshore Solutions (OSBV), based in IJmuiden, The Netherlands, developed the Offshore Access Systems (OAS).

Conceived in 2003, the OAS is a 21-metre hydraulically operated telescopic gangway, fitted with an active heave-compensation system. It incorporates a motion reference unit in its active hydraulic system which, when engaged, maintains the walkway tip at a constant height relative to the horizon. This allows the gangway to safely connect to a fixed offshore structure in sea states of up to three-metre significant wave height (Hs) when installed on a suitable vessel.

The gangway connects to a landing station installed on the offshore structure by means of a hydraulically operated gripper-head. Once connected, the heave compensation is disengaged, allowing the transfer of personnel to commence.

With its own independent power source, the OAS can remain operational, even in the event of vessel power failure. The OAS has the unique ability to offer 24-hour connectivity, enhancing operational efficiency by allowing sustained personnel transfer to take place, 24 hours a day.

Should an emergency disconnection be required, the gripper-head has a fail-safe mechanism that allows automatic release from the landing stationâ&#x20AC;&#x2122;s connection pole. This system allows an emergency vessel sail-away to be performed without the need for operator intervention. In the event of this situation, the walkway automatically reactivates the heave compensation system, allowing a controlled and safe retrieval of the gangway to its boom-rest on the vessel.

In July this year, OSBV launched its freestanding OAS, designed to allow further efficiency and cost reduction through a decrease in the time required to install the system on a vessel. The new design allows quayside installation to be completed in a day, eliminating the need for structural modifications to the vessel (previously required to accommodate the pedestal both above and below the deck). The free-standing OAS is precommissioned and, once installed on a suitable vessel, is ready for immediate operation.

Offshore Solutions is widely-recognised as being able to offer one of the safest methods of facilitating personnel access to offshore

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essential. www.marellimotori.com

Technical Focus

S15 ORME 1 2012 Technical Focus 03_Layout 1 31/01/2012 15:22 Page 76

Step change The development of the OAS has brought a step change to access solutions for the offshore oil & gas and wind industries. Since commencing commercial operations five years ago, operators now have a safe and cost effective solution for undertaking construction, maintenance and decommissioning work.

The OAS has been widely recognised for its innovative technology winning numerous awards; The IChemE Merck, Sharpe and Dhome award for excellence in safety in 2006, the Energy Institute's award for innovation and costeffectiveness with major applications for the oil and gas industry 2006, The American Society of Mechanical Engineers (ASME) Woelfel Best Mechanical Engineering Award at the Offshore Technology Conference in Houston 2009 and most recently (together with GDF SUEZ E&P Nederland B.V.) the GDF SUEZ Grand Prix de L’innovation, in the category of Field Operations.

Developments Free standing OAS

installations, having completed over 7,500 successful connections and in excess of 90,000 transfers since operations began in 2006, with zero recorded incidents.

During 2011, in the Gulf alone, the OAS has run for more than 2,500 hours with 100 per cent availability. During this period, more than 20,000 personnel transfers have taken place without any safety incidents.

Cost savings Operating and maintaining normally unmanned installations (NUIs) in harsh offshore conditions using helicopters to transfer the workforce, means that many hours are lost through shuttling procedures and downtime due to adverse flying conditions.

Having an OAS-equipped vessel with accommodation in the field, means that personnel can be transferred to the installation at the start of their 12-hour shift. Several installations can be serviced by one vessel and with available manhours on each installation increasing by up to 70 percent by using an OAS, this equates to very significant cost savings for the operator.

The cost per bed is also less than a Jack-Up accommodation unit and with multi-function capability, the OAS vessel can also be used as a standby vessel, to facilitate ROV or dive spread, dive support, workshops, materials storage and platform supply.

Track record Most recently, Offshore Solutions has been providing 24/7 personnel access in the Middle East for Qatar Shell GTL Ltd. (Qatar Shell), operator of the world’s largest gas to liquids plant – the world’s first heave-compensated access system to work in the region. The OAS has been used to

76 Oil Review Middle East Issue One 2012

With its own independent power source, the OAS can remain operational, even in the event of vessel power failure transfer crews to the Pearl 1 Platform, positioned in The Gulf, since the completion of sea trials in December 2010. Pearl 1 is one of two platforms providing offshore gas to the Pearl Gas to Liquids (GTL) project in Qatar.

Using the 21-metre OAS mounted on the Bourbon Gulf Star vessel, the Qatar Shell operations, project and maintenance personnel were able to access the platform 24-hours a day.

The OAS’ continuous connection capability was a key element of this marine access success story.

As well as the robust physical connection, this OAS was specifically adapted to perform for extended periods in demanding climatic conditions.

Despite a challenging environment affected by a range of weather conditions and sea states, the unique continuous 24-hour connection capability allowed staff to leave the platform for the vessel during periods of high temperature and humidity; returning to work during cooler periods of the day - a demonstration of the flexibility and efficiency of the OAS. The Bourbon Gulf Star with OAS mounted onboard will also enable personnel transfer to Pearl 2, aiding Qatar Shell in bringing the second platform on line.

The contract was awarded based on the OAS’ proven technology, safety record and the potential to increase operational efficiency.

There are further opportunities to explore in the development of marine personnel transfer and Offshore Solutions is committed to the continuous advancement of marine access.

Design has now been completed for a development to the standard OAS. The elephant’s foot connection has already been successfully trialled at OSBV’s factory facility using a prototype unit. As a result of this, OSBV has commenced production, and certification has been applied for on this additional connection methodology. This new technology will expand the ability of the OAS to be utilised on installations with little or no preinstallation requirements.

The connection detail for the elephant’s foot is based on friction interface, which defines the contact area used for the foot itself - 1m x 1m.

Proximity sensors are fitted to the foot to sense when it is grounded. This allows the system to change from active to passive.

Meanwhile, the overriding design principles of the OAS are being retained in terms of a robust connection and minimal disruption to the operation. The production model will be in operation by end of 2011.

Delivering flexible and safe marine access solutions is Offshore Solutions’ core business, as well as continuing to maintain its reputation for providing a credible, efficient and cost effective alternative to current transfer methods.

Offshore Solutions is convinced that marine access systems will be increasingly used in the transfer of personnel to offshore structures in the future and is noticing that operators worldwide are beginning to challenge their existing operating models.

Moving towards marine access as an alternative way of liquidating man-hours offshore will increase personnel availability on location, improve productivity and with a multi function vessel, will help operators to reduce the cost of construction, maintenance and decommissioning work at offshore work sites. ■

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Information Technology

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PDO to tackle technology challenges with ITF membership PETROLEUM DEVELOPMENT OMAN (PDO) has joined ITF, the technology facilitator for the global oil and gas industry, to help drive new solutions forward with other major oil and gas players in the region. The government and industry owned company believes technology is the key to securing and maximising reserves and delivering Enhanced Oil Recovery (EOR).

Sultan Al-Shidhani, study centre manager for PDO said: “Joining ITF provides us with the opportunity to address the technology challenges we are facing in a joined up approach with other operators.

“Oil in Oman is becoming more challenging to develop with a rising number of EOR and sour (hydrogen sulphide) projects, so technology has a growing role to play. We believe that collaborating on joint industry projects will help to bring forward the technologies that can assist continued recovery.”

The company joins other high-profile Middle East members including Kuwait Oil Company (KOC) and Saudi Aramco in joining ITF in order to support international technology development.

The agreement reinforces ITF’s commitment to the Middle East after it set up an office in Abu Dhabi in 2011.

Ryan McPherson, ITF’s regional director in the Middle East and Asia Pacific welcomed PDO’s membership. He said: “This is an important signing for us as growing our membership in the Middle East is crucial to funding the game-changing technologies that will make the biggest difference in this environment. We understand that operators are facing the prospect of increasingly complex projects and believe that ITF will play a major role in solving some of those challenges.”

Left to right: Ryan McPherson, ITF’s regional director in the Middle East and Asia Pacific meets Dr Riyadh Moosa and Sultan Al-Shidhani from Petroleum Development Oman in Aberdeen

ITF is planning to launch a Gulf Co-operation Chapter this year with Middle East operators, with the task of focusing mainly on setting and solving regional technology challenges.

ITF members share funding and risk on bringing forward new solutions through joint industry projects (JIPs). Innovators are offered up to 100 per cent funding to develop their technology and retain full intellectual property rights. To date ITF has launched more than 170 JIPs from early stage projects through to field trials and commercialisation. ITF aims to secure a further US$75mn to launch 40 JIPs per year by 2015.

For more information on ITF, visit: www.oil-itf.com

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78 Oil Review Middle East Issue One 2012

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Information Technology

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New land seismic products

New plug-in for petrophysics interpretation

INOVA GEOPHYSICAL ANNOUNCED the introduction of five new products distinctly designed to infuse greater flexibility into land seismic operations.

These technological advancements will provide geophysical contractors and E&P companies with more options while addressing key challenges around the industry's emerging trends. Together, all of these new or redesigned technologies address common industry concerns and offer opportunities for productivity gains.

The announcement marks the beginning of the most significant product launch since the formation of the company in 2010. INOVA Geophysical is a global independent land seismic equipment manufacturer formed as a joint venture of BGP, the world's largest land seismic contractor, and ION Geophysical, a leading technology-focused seismic solutions company. Though a relatively young company, by leveraging the array of ION's state-of-the-art, pioneering land seismic technology combined with BGP's operational experience, INOVA has been able to quickly produce advanced seismic land technology with real positive impact. This is an exceptional quantity of new products for a geophysical equipment manufacturer and demonstrates the company's commitment to listening to its customers and quickly providing viable solutions to their problems. Of interest to the geophysical community is the launch of a new cableless platform of land acquisition systems. Equipment operators are increasingly turning to cableless seismic operations to overcome obstacles, reduce footprint and comply with environmental regulations. Following this trend, INOVA now offers two cableless systems: the redesigned FireFly® DR31 and a new autonomous node Hawk™ SN11 recording system.

DGB EARTH SCIENCES, the leading provider of open source seismic interpretation software to the oil & gas industry, and Argentinean geosciences company, Geoinfo SRL have announced the launch of a new OpendTect plug-in for the incorporation of petrophysical properties into the seismic interpretation process.

The CLAS (Computer Log Analysis Software) plug-in, developed by Geoinfo and through which well log petrophysics can be performed within OpendTect rather than having to be imported, will result in improved well-to-seismic ties, the enhanced calibration of seismic attributes to reservoir properties, more robust models, and the more accurate interpretation of 3D seismic data.

With CLAS, seismic interpreters can edit well logs and generate vital information on oil in place through data on the saturation, clay volume, porosity, lithology and fluid content of the reservoir. CLAS will also allow net pay to be estimated from seismic attributes and will be able to use dGB’s neural networks plug-in to generate acoustic logs. The result will be the building of accurate models and improved acoustic and elastic impedance inversion.

KPC keeps pace with data management COMMVAULT ANNOUNCED THAT Kuwait Petroleum Corporation (KPC), a leader in providing safe and clean energy to the global markets, has replaced its legacy Symantec NetBackup software with CommVault® Simpana® 9 to meet expanding business, compliance and data management requirements. According to KPC, Simpana Backup and Recovery software delivers the performance, reliability and manageability to better protect critical data, which they expect will double within a year, while accommodating an ever-shrinking backup window.

With Simpana software, KPC now reports being able to safeguard vital applications, including Microsoft Exchange and Oracle ERP, along with an

expanding VMware environment, and enabling data recoveries in minutes, not hours or days, as it took previously. KPC’s IT team also relies on Simpana Archive software to streamline management of 15,000 Microsoft Exchange mailboxes and has reported a 30 per cent decrease in storage consumption. This significant decrease in storage consumption is in part due to CommVault's embedded deduplication software which has reduced redundant data by 60 per cent.

“Prior to CommVault software, we faced a lot of difficulties managing our backups and restoring data was a nightmare, so we had a poor RPO and RTO window. Not any more, though, as Simpana software’s intuitive GUI makes backup and

recovery as easy as a click of a button”, said Mr. Qais AlDoub, senior IT systems analyst, Kuwait Petroleum Corporation.

Simpana software delivers data management improvements across the company’s entire data center comprising both physical and virtual servers.

This has proved to be highly beneficial given the fact that KPC has virtualised nearly 70 per cent of its environment. The company also credits CommVault’s centralised, unified management platform with increasing operational efficiencies through simpler, faster daily backups and restores.

Meanwhile, integrated reporting has streamlined compliance audits in keeping with KPC’s evolving information governance requirements.

Improving communications in Qatar FERN COMMUNICATIONS LTD, a leading bridge of the vessel and the FPM, located at sea provider of two-way radio communications level. This was causing the radio signal to break systems to the international upstream oil and down, making communications between the gas industries, today announced that for the bridge and vessel crew haphazard at best. first time its FRX-1 radio repeater has Because radio communications are essential to undergone field trials conducted offshore timely and accurate communication of the Qatar. The outstanding performance of Fern tanker’s position in relation to the FPM, it is Communications’ radio technology for extremely important that the radio signal Qatargas led the company to purchase FRX-1 remain strong. radio repeater systems as part of its standard In an effort to provide uninterrupted radio suite of radio communications equipment for communications between the bridge and the Pictured with the Qatargas crew during field trials conducted offshore crew, Qatargas welcomed Fern Communications’ use offshore. Qatargas contacted Fern Qatar is (third from right) Clive Cushion, Technical Director of Fern offer to test the effectiveness of the FRX-1 Communications with an offshore Communications, with the FRX-1 radio repeater, which provided onboard a tanker while normal loading communications problem they hoped the FRX- uninterrupted radio communications during loading operations. operations were being carried out.

1 might help them to solve. It seemed that During a four-day period, the Fern Communications team worked with members while loading condensate from the various natural gas condensate fixed point of the crew onboard a condensate tanker to demonstrate two FRX-1 units, both mooring (FPM) outlets offshore, it was necessary to position the bow of the UHF and VHF. By positioning the FRX-1 unit at strategic points on the vessel, tanker directly in front of the FPM. Unfortunately, the radio communications the radio signal was able to travel from one crew member’s radio around the signals used while carrying out these manoeuvres was repeatedly attenuated by steel structure to the receiving crew member’s radio. the steel structure of the tanker, which lies within the line of sight between the

80 Oil Review Middle East Issue One 2012

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Under the patronage of His Royal Highness Prince Khalifa bin Salman Al Khalifa Prime Minister of the Kingdom of Bahrain

10th Middle East Geosciences Conference and Exhibition Bahrain International Exhibition and Convention Centre 4 â&#x20AC;&#x201C; 7 March 2012 The Middle East's Premier Geoscience Event

www.Geo2012.com

Information Technology

S16 ORME 1 2012 IT_Layout 1 31/01/2012 15:26 Page 82

Sysdrill suite selected

Enhancing virtualisation solutions

PARADIGM ANNOUNCED THAT Geopro Technology Limited (www.geoprotech.com) has selected the Paradigm™ Sysdrill® suite as their internal drilling engineering solution. The decision was made after a comprehensive evaluation process conducted by the company.

Geopro, a provider of engineering solutions to the oil and gas industry, will use Sysdrill to accurately model challenging wells to reduce cost and improve safety for the benefit of its operating company customers.

The Paradigm Sysdrill suite of drilling engineering modules is delivered in a single application running within Paradigm’s Epos® integrated geoscience and engineering data management system. Sysdrill maintains a robust, scalable database from wellsite to corporate data store, including an option for rigorous user access control suited to large organizations.

INOVX SOLUTIONS, INC., which claims to be the leader in Asset Virtualization® solutions for the process industries, announces the release of version 5.5 of its RealityLINx® software. RealityLINx v5.5 includes a number of performance, functional, and usability enhancements. This release features improvements such as reduced memory usage allowing for display of significantly larger models. The new RealityLINx release also supports opening multiple projects enabling users to perform most display, query and authoring functions in more than one project in a single RealityLINx session. Combined the enhancements constitute a significant performance increase.

Users will also discover a number of functional and usability improvements in this release such as ‘Fixed Frame Rate’ to provide a more fluid user interaction while navigating large virtual plant models as well as the ability to customize the units of measure differently than the default for the Project. The use of 3D laser scanning to capture as-built geometry of complex facilities has grown rapidly.

This technology is driving improvements in the accuracy and completeness of Asset Documentation, providing customers with a foundation for better safety and environmental compliance. In addition, industry is increasingly taking advantage of intelligent 3D models developed from laser scan data in order to drive new efficiencies in work processes.

www.pdgm.com

Keeping companies compliant LOGICA, A LEADING business and technology service company, has signed an Alliance Partnership Agreement with OpenText and the EPIM association (Exploration & Production Information Management) to allow joint ventures of oil and gas companies to share information and benefit from EPIM’s world-class workflows through a new collaboration architecture. EPIM is an industry driven association of 38 exploration and production companies operating on the Norwegian Continental Shelf that exists to facilitate the workflows of joint venture operations and activity reporting to authorities.

EPIM’s role is to facilitate the best possible flow of information between the partners that

operate a joint venture. Joint venture administration can represent an administrative burden with complexity easily spiralling. EPIM chose Logica¹s expertise to make substantial upgrades to its existing information platform and move it to a cloud-based managed service.

EPIM’s best practises involve the joint venture administration of exploration permits, production reports and transport licences, which means that EPIM participants can be confident that their licenses to operate are up to date and compliant.

The new architecture, License2Share, is based on OpenText¹s ECM Suite 10 for enterprise content management and incorporates role-based workflows and directories.

Aiding exploration in Tajikistan ARKEX, THE PROVIDER of geophysical imaging services, has completed a G-Qube airborne gravity gradiometry survey in Tajikistan for Tethys Petroleum Limited. The G-Qube survey, incorporating gravity, gravity gradiometry and magnetic data, covers the majority of the 35,000 sq.km Bokhtar Production Sharing Contract (PSC) area. The Bokhtar PSC lies to the south-west of Tajikistan bordering Uzbekistan and Afghanistan and has great potential.

G-Qube is the ideal technology for surveying prospective areas that are located in remote and inaccessible terrain. The survey will help map the areal distribution of salt, provide depth to basement/basement surface architecture and image sub-salt carbonates. When integrated with the 2D seismic data, which is already in place, Tethys will have a more robust structural model from which to develop the area further.

82 Oil Review Middle East Issue One 2012

www.arkex.com

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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.

THIS MONTH Country

VARIANCE LAST MONTH

LAST YEAR

Oil

Gas

Misc

Total

Oil

Gas

Misc

Oil

Gas

Misc

Total

ABU DHABI

17

2

0

19

-3

-1

0

20

3

0

23

BAHRAIN (1)

4

0

0

4

0

0

0

4

0

0

4

CYPRUS (1)

0

1

0

1

0

0

0

0

1

0

1 0

Middle East DUBAI

0

0

0

0

0

0

0

0

0

0

IRAN

0

0

0

0

0

0

0

0

0

0

0

IRAQ

0

0

0

0

0

0

0

0

0

0

0

ISRAEL (1)

1

1

0

2

0

-1

-1

1

2

1

4

JORDAN

0

0

0

0

0

0

0

0

0

0

0

KUWAIT

27

5

0

32

-1

-1

0

28

6

0

34

OMAN

39

11

0

50

2

0

0

37

11

0

48 15

PAKISTAN

6

6

0

12

-1

-2

0

7

8

0

QATAR

6

2

0

8

3

-1

0

3

3

0

6

SAUDI ARABIA

48

28

0

76

0

2

0

48

26

0

74

SUDAN

0

0

0

0

0

0

0

0

0

0

0

SYRIA

27

0

0

27

0

0

0

27

0

0

27

2

0

0

2

-1

0

0

3

0

0

asas

117

56

0

289

0

-3

-1

178

60

1

236

YEMEN TOTAL

North Africa ALGERIA (1)

23

9

1

33

2

-2

0

21

11

1

33

EGYPT

53

18

0

71

1

1

0

52

17

0

69

LIBYA***

0

0

0

0

0

0

0

0

0

0

0

MOROCCO (1)

0

0

0

0

0

0

0

0

0

0

0

TUNISIA

1

0

0

1

0

-1

-1

1

1

1

3

TOTAL

77

27

1

105

3

-2

-1

74

28

2

105

Source: Baker Hughes

84 Oil Review Middle East Issue One 2012

S17 ORME 1 2012 Arabic_Layout 1 31/01/2012 15:40 Page 85

S17 ORME 1 2012 Arabic_Layout 1 31/01/2012 15:40 Page 86

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Following the success of Saudi Downstream 2011, hosted by the Royal Commission for Yanbu. We are delighted that next year’s meeting will be held in Jubail, Kingdom of Saudi Arabia in March 2012. Saudi Downstream Strategic Forum & Exhibition remains your gateway to the Kingdom’s downstream industries - where real decision makers are shaping tomorrow’s investments.

www.saudidownstream.com

Saudi Innovation, Diversification & Investment (SIDI) is the heart of wealth and job creation in Saudi. The event will focus on projects and local content strategies that will add real commercial value to the private sector and that will diversify the economic outlook of the Kingdom. SIDI looks at how projects impact job creation, technology hnology transferr, development of talents and a leadership, capacity building, project optimisation and best practices.

www.sidiforum.com

The Global Water: Oil & Gas Summit will discuss, the current role and demand of water in the oil and gas industry, address technological shortfalls, reflect on solutions and provide the perfect networking platform for leading experts to discuss similarities, opportunities and experiences of water within the oil and gas industry.

www.cwcoilgasandwater sandwaterr..com

As Iraq seeks increasing support from international oil, gas and service companies for economic development, Iraq Petroleum 2012 will host the largest gathering of over 300 senior level executives and industry experts from over 90 companies worldwide, providing an ideal forum to discuss these developments as well as the oppotunity to network and build relationships.

www.cwciraqpetroleum.com

Following the unprecedented ented success of the SWPFF, CWC is delighted deligh to announce the launch of the Arabian Water & Power Forum, under the Royal Patronage of HH Sheikh Mohammed Bin Maktoum Bin Juma Al Maktoum. AWPF W will w form the meeting point for key government and industry figures to discuss, debate and generate those strategies and policies crucial in the forward development of a sustainable water-energy balance.

www.cwcawpf.com

Following the success of Iraq Mega Projects 2011, the IMP Teeam confirm that the event will take place again in 2012, this time in Dubai. Senior Iraqi professionals, contract holders and representitives from the service industry will discuss the recent progress since the signing of the contracts, the challenges they have overcome and the problems they are facing.

www.cwcimp.com

As it grows in stature each ach yearr, and as a catalyst for change and innovation, the Saudi Water & Power Forum plays a key role in uniting Saudi and international stakeholders to discuss the policies and strategies which will determine the future of the power and water sector in the Kingdom. SWPF includes the international exhibition, which provides the platform for companies to showcase their products, services and expertise.

www.ksawpf.com

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S17 ORME 1 2012 Arabic_Layout 1 31/01/2012 15:41 Page 93

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ADVERTISERS INDEX Company ......................................................................................Page AES Arabia ..................................................................................................................49 Al Mansoori ................................................................................................................15 ALAA Industrial Equipment Factory ......................................................................59 All World Exhibitions (MEP 2012)..........................................................................19 All World Exhibitions (GEO 2012) ..........................................................................81 Asturi Metal Builders (M) SDN BHD ......................................................................57 Baumer Group ............................................................................................................11 Bredero Shaw ............................................................................................................13 Cansco Dubai LLC ......................................................................................................51 Cargotec Fzco ............................................................................................................43 Cudd Energy Services ..............................................................................................55 CWC Associates Ltd ..................................................................................................90 Dome Exhibitions (SOGAT 2012) ............................................................................85 Draeger Safety............................................................................................................46 Duferco ........................................................................................................................23 Emerson Process Management ................................................................................7 Emirates ........................................................................................................................2 Etihad Airlines ............................................................................................................27 Eugen Seitz Middle East ..........................................................................................61 Expotim International Fair ORG. INC (Basra Oil & Gas 2012) ..........................63 Gates Engineering & Services ................................................................................47 GE Energy ....................................................................................................................39 Geyad For Commerce & Import Co. Ltd. ..............................................................46 GRACO BVBA..............................................................................................................45 Hempel Paints Bahrain ............................................................................................77 Hi-Force Ltd ................................................................................................................25 Honghua Golden Coast Equipment FZE ................................................................40 Hydroflow Pump Rental Est ....................................................................................59 IIR Exhibitions (MEE 2012) ......................................................................................73

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International Exhibition Services Srl (SAOGE 2012) ..........................................71 Jotun Paints U.A.E. Ltd (LLC)......................................................................................3 Kaeser Kompressoren FZE ......................................................................................67 Kohler Power Systems..............................................................................................57 Marelli Motori S.p.A. ................................................................................................75 Metscco Heavy Steel Industries Company Limited............................................95 Microtest AG ..............................................................................................................79 MSA Middle East ......................................................................................................53 National Pipe Company............................................................................................55 Oil Country Tubular Ltd (OCTL)................................................................................65 Oman Cement Company ..........................................................................................35 OmanExpo ..................................................................................................................83 OutoKumpu Armetal ................................................................................................56 Petrotech Enterprises (L.L.C.) ..................................................................................87 Prakash Steelage Ltd. ..............................................................................................37 Sabin Metal Corporation ..........................................................................................29 Saga PCE Pte Ltd ......................................................................................................31 Schlumberger Technical Services, Inc. ....................................................................4 Schneider Electric IT Logistic Europe ....................................................................41 Shree Steel Overseas FZCO ....................................................................................30 Sin Hiap Chuan Hardware and Engineering Pte Ltd ..........................................55 Society of Petroleum Engineers ............................................................................58 SOUTHERN CALIFORNIA VALVE ..............................................................................78 Specialized Oilfield Products ....................................................................................9 Suraj Limited ..............................................................................................................25 Tenaris..........................................................................................................................21 TMK ..............................................................................................................................17 Veritas-MSI China Company Limited ....................................................................82 VF Imagewear/Bulwark............................................................................................33

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S17 ORME 1 2012 Arabic_Layout 1 31/01/2012 15:41 Page 96