Oil Review Middle East issue 3 2012

ORME 3 2012 Cover_ORMETHREE05COVER.qxd 05/04/2012 14:25 Page 1

Vol 15 Issue Three 2012

www.oilreview.me

Oil Review Middle East - Volume 15 - Issue Three 2012

UK £10, USA $16.50

Turmoil constrains regional investment Bahrain in gas import talks Oil reserves not for release - IEA Yemen facing the prospect of further unrest Feedstock shortage threatens petrochemical producers Corrosion inhibitors ‘go green’

PDO delivers another production boost

The benefits of wireless sensor networks Hydraulic fracturing - reducing environmental risks The growth in digital oilfields

See us at these events

www.oilreview.me

As the world’s largest oil and gas producing region, the Middle East is a natural magnet for drillers and a key location in the global rigs market.

See page 72

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Vol 15 Issue Three 2012

Contents

www.oilreview.me

UK £10, USA $16.50

Turmoil constrains regional investment Bahrain in gas import talks Oil reserves not for release - IEA

Columns

Yemen facing the prospect of further unrest

6

Industry news and executives’ calendar

Feedstock shortage threatens petrochemical producers Corrosion inhibitors ‘go green’

PDO delivers another production boost

The benefits of wireless sensor networks Hydraulic fracturing - reducing environmental risks

Analysis

The growth in digital oilfields

16

Yemen

See us at these events

Further attacks on the Yemen’s oil and gas infrastructure are inevitable, according to experts at Exclusive Analysis.

As the world’s largest oil and gas producing region, the Middle East is a natural magnet for drillers and a key location in the global rigs market.

See page 72

18

Outlook

ars

ye

Exploration & Production 22

The latest exploration and production news from around the region.

Gas 30

Analysis Abu Dhabi announced plans to build an import terminal for LNG at Fujairah.

Petrochemicals 36

Outlook A shortage of natural gas feedstock threatens the region’s dominance as the most economical petrochemicals producer.

15

Oman continues to defy the odds when it comes to production.

Photo courtesy of PDO

GL Noble Denton and the Economist Intelligence Unit have launched a new report.

Developments

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

Editor’s note OMAN’S OIL AND gas reserves may not quite match those of fellow Gulf producers but that has not stopped the Sultanate from making the most of what it does have. The country is still a major oil and gas exporter in its own right, though not a member of the OPEC. And what a job Petroleum Development Oman (PDO) has done in recent years by turning around Oman’s dwindling production volumes, to restore output to former levels and pocket precious more income for the government as it continues to expand and diversify the economy beyond hydrocarbons. Other regional producers could learn a lot from PDO’s upstream engineers who are meeting the challenge of complex reservoir systems and ageing fields head on to boost the nation’s oil and gas production year-by-year.

PDO Review 41

Profile

50

Oman’s oil and gas sector remains quite vibrant, and the forthcoming OGWA event will highlight the sultanate’s expanding energy plans.

Caspian Oil & Gas Exhibition

Gianni Minetti, President and CEO of Paradox Engineering SA, examines wireless sensor networks and their applications for remote and condition monitoring of oil and gas sites.

82

Hydraulic Fracturing Why propped hydraulic fracturing reduces environmental risks.

87

55

Interview

55

Oil Review recently spoke to Brice Bouffard, Vice-President of Petroleum Consulting, Weatherford and Bob Kuchinski, Business Development Manager, Weatherford about the launch of the company’s new business unit, Petroleum Consulting.

Azerbaijan has capitalised on its large hydrocarbon resources and continues to encourage foreign direct investment in its oil and gas industry.

ADIPEC 2012

78

Wireless Sensor Networks

Exhibitions and Conferences Oil and Gas West Asia

76

Wireless Technology

Honeywell Process Solutions says a growing emphasis on wireless technology can bring major benefits to the oil and gas sector.

Upstream engineers at Petroleum Development Oman (PDO) are confronting the challenge of complex reservoir systems and ageing fields head on to boost the sultanate’s oil and gas production.

Canadian companies already have an eye on the region’s biggest oil and gas event.

IT & Communications 88

Technical Focus

Digital Oilfields

Innovations

57

Sami Suheil, CEO of Monitor spoke to Oil Review about the growth of digital oilfields in the region.

68

News and Developments

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

Corrosion Prevention

The development of a new class of environmentally acceptable corrosion inhibitors for oil and gas fields is now a reality.

72

Rigs

The region continues to provide a reliable source of work for drillers despite global oil demand fears.

90

The latest communications and IT news from the regional oil and gas sector.

Arabic Section 5 11

News Analysis

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

Publisher: Nick Fordham

Advertising Sales Director: Pallavi Pandey

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Email ying.mathieson@alaincharles.com tanmay.mishra@alaincharles.com bola.olowo@alaincharles.com mne@acpmos.ru annabel.marx@alaincharles.com saida.hamad@alaincharles.com stephen.thomas@alaincharles.com michael.tomashefsky@alaincharles.com

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

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

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Oil Review Middle East Issue Three 2012 5

Industry News & Events

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Regional oil and gas reserves worth US$65 trillion THE GCC'S HYDROCARBON reserves are estimated to be worth around US$65 trillion at current export prices, based on new analysis from QNB Capital. This is almost a third of the US$200 trillion value of world oil and gas reserves.

To put US$65 trillion in context, it is equivalent to 47 times the GCC's estimated GDP in 2011, or 93 per cent of global GDP. It is also 125 times the estimated US$521 billion that the region's governments received in oil and gas revenue during 2011.

The rest of the MENA region has the next largest share of global hydrocarbon reserves (23 per cent), particularly in Iraq and Iran, followed by Europe and Eurasia (16 per cent), mainly Russia and Kazakhstan. In volume terms, the GCC's 495 billion barrels of oil account for 36 per cent of global oil reserves and its 42 trillion cubic meters of gas are 22 per cent of global gas reserves.

Splitting down the total hydrocarbon reserves by country shows that Saudi Arabia represents

almost half the GCC total, followed by the UAE, Kuwait and Qatar which each have around a sixth of the total. Qatar's share is worth about US$9.5 trillion. Oman has only 1.2 per cent of the regional total and Bahrain less than half that amount.

These estimates are only indicative as hydrocarbons prices are volatile and hard to predict given that they are influenced by a number of factors. These factors include world economic growth, geo-political risk, energy efficiency and technological advancements. If the lower hydrocarbon prices recorded in 2009, which can be seen as a worst case scenario, were used in QNB Capital's calculation, then the reserves would be worth (only) US$42 trillion.

As gas prices vary considerably between countries, unlike oil prices, QNB Capital assumed a gas price of about US$7.5 per thousand cubic feet, an average of US, European and Asian pipeline and liquefied natural gas (LNG) import prices.

This is a reasonable estimate of what gas is currently worth to the main importing countries. At these prices, it would cost about $40 to purchase a volume of gas that produces the same amount of energy as a barrel of oil. Therefore, exported gas is worth just over a third of the oil price, which is estimated at US$109 a barrel in 2011.

Gas can be regarded as even cheaper relative to oil if environmental costs are taken into account as it is a cleaner burning and more efficient fuel. Therefore, it is possible that, as technology makes it cheaper and easier to transport and use gas (including in vehicles), its discount to oil may reduce. This would increase the value of gas reserves relative to oil reserves.

QNB Capital also stated that its calculations may be an underestimate because new reserves will probably be found. Also, technological advances and high prices will make a larger share of the existing in reserves commercially exploitable.

Unrest constrains regional investments

Iraq approves Hormuz plan

THE PREVAILING UNREST in certain areas of the Middle East and North Africa, along with rising costs, will hamper investment in the upstream hydrocarbon sector, a report by the Arab Petroleum Investment Corporation (Apicorp), an affiliate of the 10-nation Organization of Arab Petroleum Exporting Countries (OAPEC), said recently.

Although the region is home to more than 60 per cent of the world's extractable oil deposits, investment in hydrocarbon projects by MENA countries is estimated at only around US$2.7 trillion until the year 2035, a fraction of the total global energy projects worth nearly US$37.5 trillion, the report noted.

It cited a report by the International Energy Agency (IEA) showing oil supply accounts for US$10 trillion, representing 26 per cent of the total capital.

The report, written by Apicorp's senior consultant Ali Aissaoui, said natural gas accounts for US$9.5 trillion, representing 25 per cent while coal projects are estimated at US$1.2 trillion, nearly three per cent and biofuels at US$400 billion, accounting for about one per cent.

The highest share is that of the power sector, which includes electricity generation, transmission and distribution systems. This sector accounts for US$16.9 trillion representing 45 per cent of global energy supply investment.

The report noted that cost inflation is the most important factor driving the increase in energy investment in MENA and other parts of the world.

IRAQ HAS APPROVED a plan to expand its oil export routes by adding capacity from its northern fields and building a pipeline to ship oil from southern fields to Ceyhan in Turkey, a government spokesman said.

The contingency plan was set by the government's energy and economic committee to deal with any potential crisis should Iran close the Strait of Hormuz, which would halt about 80 per cent of Iraq's oil exports. Iran has threatened to close the Strait of Hormuz, used for a third of the world's seaborne oil trade, Strait of Hormuz - will Iran close it? if Western moves to ban Iranian crude exports crippled its energy sector. 'Short and mid-term plans will be through boosting crude pumping and upgrading export capacity via Ceyhan port in Turkey. Also to increase the number of trucks that are shipping crude,' government spokesman Ali al-Dabbagh said.

6 Oil Review Middle East Issue Three 2012

S02 ORME 3 2012 News_Layout 1 05/04/2012 14:53 Page 7

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Industry News & Events

S02 ORME 3 2012 News_Layout 1 05/04/2012 14:53 Page 8

Greater automation and integration needed OIL REVIEW SPOKE to Bjarne-Andre Asheim, Regional Business Unit Manager Oil, Gas and Petrochemicals for ABB in the Middle East about the growing demand for greater integration of automation in the hydrocarbon sector and what ABB is doing to bring this about. Asheim explained that ABB was trying to use its considerable experience to bring innovative products to the rest of gas and petrochemical sector. “In the oil and gas and petrochemical fields, ABB provides all solutions within automation, telecom, and electrification,� he said. “We see more and more focus within the electrification part.�

Asheim argued that the increased focus on energy efficiency within other industries is now coming to the oil, gas and petrochemical market. “We can see that there can be huge savings just by applying the existing technology we have already today,� he said. “We can use this in the oil, gas and petrochemical market and huge savings can be found, especially in the Middle East market.�

Asheim discussed the different oil and gas sector trends and said that there is currently a growing emphasis on the greater integration of electrification and automation.

“This will result in more and more integration of data and a greater use of smart applications all the way from the transmitters to the ERP systems,� he said. “The full integration of data from different systems will soon be a requirement in all oil, gas and petrochemical plants. “ABB offers solutions within the whole value chain and it is where we can provide a huge saving to our clients. For instance in stressful operations you need to provide solutions and consolidated or pre-treated data to the operator that makes him more effective in his work. “The market for operator effectiveness and high performance HMI (human machine interface) is going to be a differentiator for the future. That is why we have focused a lot around what is basically all about empowering the operator. We develop more and more solutions for this that become smarter and smarter.�

Asheim stated that the whole of the Middle East is ABB’s target market, with the UAE, Saudi Arabia, Qatar, and Iraq seen as key markets. He also discussed the importance of the growing petrochemical sector. “We had a major break through with the Sadara project which was a big win for us and it is great to see the success,� said Asheim. “The solutions we

talked about and total integration will be there.

Everything is going to be integrated with an ABB system and this will see our Saudi Arabia operations grow a lot.�

Asheim said that the growth of the gas market over the last few years will be increasingly important for the company. “GTL is now coming up which will be very exciting to see what the usage of this will be,� he said. “Gas is going to play a more and more important role.�

Asheim feels that digital oilfields “are very interesting and is a growing interest in the region.

The digital oilfield integrated operations are becoming more relevant when you go in from peak production to tail production. You want to get more out of your reservoir and lower your costs.�

The EOR market is really picking up in Saudi Arabia and Oman, which has been involved in this area for quite some time, has been able to get production levels up, making this remain a focus for Oman. In the UAE it is a real focus and it will become a focus for Kuwait and Qatar in the future. “We are in the best position for this market and we have seen this in other regions and we have lots of references for this. ABB is well positioned for EOR.�

Lamprell’s profits boosted by increase in orders LAMPRELL ANNOUNCED THAT its revenues increased 127.8 per cent to US$1.14 billion last year. Its adjusted net profit was up 10.8 per cent to US$73.8mn from US$66.6mn in 2010.

In 2011 the group was awarded a record US$1.1 billion worth of contracts, the company said.

"We're very pleased with the numbers," said CEO Nigel McCue, adding that the acquisition of Maritime Industrial Services Co (MIS) had significantly contributed to consolidating the company's position as a market leader in the provision of contracting products and services in the oil, www.lamprell.com gas, and renewables industry.

The acquisition of Maritime Industrial Services Co was completed in July 2011, increasing Lamprell's yard space to 925,000 square metres and the quayside to 2.2 km, which has helped expand the group's service offering, customer base and geographical range.

Last year the group undertook 43 jackup rig upgrade and refurbishment projects.

Contracts secured an additional five jackup rigs, giving the group's eight new build rigs under construction at the end of the year.

In the renewable sector for wind farm installation vessels, McCue said that Lamprell delivered two vessels and is expected to deliver three more this year.

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S02 ORME 3 2012 News_Layout 1 10/04/2012 11:54 Page 10

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Industry News & Events

S02 ORME 3 2012 News_Layout 1 10/04/2012 11:35 Page 12

Oil reserves not for release - IEA SAUDI ARABIA AND other Middle East oil exporters can be relied on to meet rising oil demand and there is no need for the release of crude from emergency reserves, according to the head of the International Energy Agency (IEA).

"Saudi Arabia and other Gulf countries said to the world that they will meet demand if the demand is there," Maria van der Hoeven, executive director of the IEA, said on the sidelines of a conference in New Delhi. "They are reliable suppliers."

Iraq and BP agree production increase THE STATE-OWNED IRAQI Northern Oil Company has signed a preliminary agreement with BP to increase the production of Kirkuk field to 580,000 barrels per day (bpd) from about 280,000 bpd.

The undersecretary of Northern Oil Company Hussein Allam said: "The initial agreement is part of a high-level plan www.bp.com carried out by the Oil Ministry through the Northern Oil Company to develop the production of the northern fields through a partnership contract signed with BP. The Kurdistan Region opposes any oil contract to develop oilfields located within the borders of Kirkuk province and other areas in which ownership is disputed between Baghdad and Erbil.

The region says that the priority is for the implementation of the constitutional article related to settling the dispute over these areas before signing any oilfield contracts.

The disputes between Baghdad and Erbil go back to the contracts signed by the latter with global companies to develop the oil fields in the Kurdistan Region. Baghdad says such contracts are illegal. The Iraqi Oil Minister Abdul Karim Luaibi said recently that the country is studying the proposals from foreign companies, including BP, to develop the Kirkuk field because the extraction of oil in these fields decreased recently.

www.iea.org

ITF boosts technology development The Paris-based agency co-ordinated the release of 60mn barrels of crude and oil products in June after Libyan output was disrupted by the uprising against Muammar Gaddafi, sending prices higher. The IEA also made supplies available during the 1991 Gulf War and after Hurricane Katrina struck rigs and refineries in the Gulf of Mexico in 2005.

Another release of strategic reserves is not warranted at the moment, van der Hoeven said. "Stock releases are about disruption of supplies and there is no disruption of supplies," she said.

Saudi Arabia can increase crude production by as much as 25 per cent immediately if needed, oil minister Ali Al Naimi said recently, seeking to allay the concern over supplies that has driven prices to the highest in three years.

Saudi Arabia has excess capacity of 2.5mn barrels a day, the minister said.

12 Oil Review Middle East Issue Three 2012

THE NEXT STEPS for collaborative technology development in the Middle East, which will include the launch of a joint industry project this year, were proposed at a recent event which brought together 30 of the region’s largest oil players.

ITF, a membership organisation of international oil and gas operator and service companies, united more than 70 senior professionals to establish a vision for collaborative oil and gas technology research and development in the GCC (Gulf Cooperation Council). The not-for-profit technology facilitator brokered discussion between the parties to tackle the most pressing technology barriers to accessing hydrocarbon reserves.

The event was sponsored by Kuwait Oil Company and chaired by James McCallum CEO and founder of Senergy, an energy services company which has an operation in Abu Dhabi. Presentations were given by ITF member companies including Kuwait Oil Company, Petroleum Development Oman, and Shell on the opportunities and some of the common challenges being experienced in the region.

Ryan McPherson, ITF’s regional director in the Middle East and Asia Pacific said: “The event was a huge success in gaining buyin from oil and gas companies and providing ITF with a clear directive to move forward with a regional group to deliver the vision for collaboration within the GCC. “There has been a clear cultural change with oil and gas companies willing to work together on the similar issues they face. The group will convene again to build on this momentum and define the key technology challenges. We also aim to launch an initial demonstrator project before the end of the year to tackle a regional technology challenge and prove how the ITF process can work.”

The next step will be to identify technology needs specific to the GCC region.

S03 ORME 3 2012 Analysis 1_Layout 1 05/04/2012 14:55 Page 13

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Industry News & Events

S03 ORME 3 2012 Analysis 1_Layout 1 05/04/2012 14:55 Page 14

Executives Calendar 2012 APRIL 2012 16-18

Oil and Gas West Asia

MUSCAT

www.ogwaexpo.com

30-3 May

Offshore Technology Conference

HOUSTON

www.otcnet.org

MAY 2012 8-10

POGEE

KARACHI

www.pogeepakistan.com

20-23

Middle East Petrotech 2012

MANAMA

www.mepetrotech.com

20-23

MEPIPES 2012 (Oil & Gas Pipelines in the ME)

ABU DHABI

www.theenergyexchange.co.uk

22-23

Global Water Oil & Gas Summit

DUBAI

www.cwcoilgasandwater.com

28-31

Heavy Oil World 2012

ABU DHABI

www.terrapinn.com/2012/howc

JUNE 2012 4-7

EAGE

COPENHAGEN

www.eage.org/events

4-8

World Gas Conference

KUALA LUMPUR

www.wgc2012.com

5-8

Caspian Oil & Gas

BAKU

www.caspianoil-gas.com/2012

13-14

IADC World Drilling Conference

BARCELONA

www.iadc.org

18-20

Iraq Petroleum 2012

LONDON

www.cwciraqpetroleum.com

STAVANGER

www.ons.no

AUGUST 2012 28-31

Offshore Northern Seas

SEPTEMBER 2012 3-6

Erbil Oil & Gas Exhibition

ERBIL

www.erbiloilgas.com

24-26

SAOGE

DAMMAM

www.saoge.org

OCTOBER 2012 2-5

KIOGE 2012

ALMATY

www.kioge.com

8-11

Gastech

LONDON

www.gastech.co.uk

NOVEMBER 2012 11-14

ADIPEC 2012

ABU DHABI

www.adipec.com

27-30

Offshore Southeast Asia

SINGAPORE

www.osea-asia.com

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

Caption

14 Oil Review Middle East Issue Three 2012

S03 ORME 3 2012 Analysis 1_Layout 1 05/04/2012 14:55 Page 15

S03 ORME 3 2012 Analysis 1_Layout 1 05/04/2012 14:55 Page 16

Analysis

Further attacks on the Yemen’s energy infrastructure are likely in the next year, say experts at Exclusive Analysis*.

Yemen facing the prospect of

further unrest J

IHADIST ATTACKS ON Yemen's energy sector have included the ramming of a refinery complex in Ma'rib and storage tankers in al-Shihr port using four suicide vehicle bombs in September 2006, the June 2008 rocket attack on the Safir refinery in Ma'rib province, the May 2008 rocket attack on the Aden refinery, the explosion of a device near the Nexen oil company's headquarters, a rocket attack on a compound in San'a housing Safer and Nexen employees in April 2008, the bombing of a liquefied natural gas (LNG) pipeline in Shabwa province in September 2010, and the 15 October 2011 double IED against the LNG pipeline supplying the Balhaf terminal, halting production at the LNG plant in which Total and Hunt Oil hold the largest shares. Al Qaeda in the Arabian Peninsula (AQAP) also has a presence in al-Rada', Bayda province, less than 70-km from the oil pipeline supplying Ras Isa. AQAP is very likely to respond to airstrikes against its position, or to military offensives against it, by mounting attacks on energy targets. However, the capture of strategic Exclusive Analysis - violent risk hotspot map assets like the Balhaf terminal would need to be preceded by a prolonged period of fighting weakening security forces. include the presidential palace, the state television headquarters, the Ministry of The group has also frequently stated that foreign energy firms are Defence and San'a University. Protesters are not likely to specifically target foreign plundering Muslims' oil wealth, and in August 2009 warned that even if US individuals, companies, or hotels, but hotels hosting political or diplomatic firms pulled out, jihadists would attack any Russian, Chinese or European firms meetings will be at risk of collateral damage during armed confrontations. who moved in to replace them. Accordingly, further attacks on energy assets in Property damage in the vicinity of protesters is likely, though this would probably Yemen are likely in the next year, even if these only target pipelines rather than be modest as it usually results from small-arms fire. larger complexes.

Separately, there is a separatist movement in the southern provinces that is Tribesmen also attack pipelines to protest government or energy firm also unlikely to support the new government. These separatist groups are very activities. Attacks not claimed by AQAP are likely to be the work of tribes. likely to protest in the southern provinces of Lahj, Aden, Abyan, Shabwa and Examples include the bombing of the pipeline supplying Ras Isa oil terminal on Hadramawt. Protests in the south are very likely to become more violent than 6 October 2011, opening fire at the Asad al-Kamil oilfield in Ma'rib province on farther north and property considered to be owned by northerners is at risk of 25 May 2010, and a number of earlier bombings of oil pipelines in Shabwa arson, shooting and grenade attacks. On 21 February 2012, in al-Mukalla, province, in Maswar (southeast of San'a), and of the Ma'rib-Salif pipeline.

Hadramawt province, security forces opened fire on a demonstration calling for a Tribesmen are also likely to kidnap energy employees, particularly around San'a boycott of February 2012 presidential elections. Roadblocks on major highways and in remote desert areas of al-Jouf, Shabwa and Hadramawt provinces. On 20 and intersections, including access routes to ports and airports, in southern January 2009, a German gas company employee was abducted in Shabwa provinces are likely. province and on 19 September 2008 two Colombian gas engineers were As with the previous government, the post-Saleh Yemeni government under kidnapped near Balhaf, Shabwa province. In both cases the perpetrators were his former vice president Abed Rabbo Mansour Hadi is unlikely to have the attempting to negotiate the release from prison of fellow tribesmen. military capability to impose its writ on all of Yemeni territory. The al-Ahmar Tribesmen regularly hijack or block fuel tankers during disputes with the family, which leads the Hashid tribal federation, and Major General Ali Mohsen government or energy firms. The San'a-Ma'rib road, which passes through the al-Ahmar, who commands the 1st Armoured Division, were key Saleh allies who Jahm and Nihm, Bani Matar and Bani Husheish tribal areas, is particularly prone played a critical role in keeping him in power for 30 years. Although they have to tribal roadblocks and hijackings; on 5 February 2010 the Jahm tribe blocked now turned against him, they are likely to maintain their influence under Hadi, military convoys and propane tankers. reducing the risk that contracts with oil firms would be reviewed.

On 25 February 2012, President Saleh officially handed power over to his Hadi's government will probably be dominated by northern tribal elites as deputy, Abd Rabbo Mansour Hadi. This has reduced the risk of large-scale protests before. As such, Saleh's removal is not likely to be followed by major in urban areas, including San'a, Ta'iz , Aden, Hodeida and Sa'da, until at least midconcessions to the southern separatists, who would be likely to seek to declare 2012. However, these are likely to resume again on a smaller scale because a an independent southern Yemeni state in the three-year outlook, although they number of opposition groups did not support the transition deal with former currently do not have the military capability to do so. â– President Saleh. This is the despite the fact that the main opposition group, the JMP, did reach an agreement with Saleh. These groups view the new government *Exclusive Analysis Ltd is a specialist intelligence company that forecasts as too close to the establishment that supported Saleh, which heightens the risk commercially relevant political and violent risks worldwide. For additional that will resume protests in San'a, Ta'iz and other cities. In San'a, protest hotspots information, www.exclusive-analysis.com

16 Oil Review Middle East Issue Three 2012

S04 ORME 3 2012 Analysis 2_Layout 1 05/04/2012 14:58 Page 17

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S04 ORME 3 2012 Analysis 2_Layout 1 10/04/2012 11:45 Page 18

Analysis

GL Noble Denton and the Economist Intelligence Unit launched the second annual report on oil and gas industry trends

Confidence returns

to oil and gas sector B

IG SPENDERS: THE outlook for the oil and gas industry in 2012, is the Economist Intelligence Unit’s (EIU) second annual industry barometer, commissioned by GL Noble Denton. The report surveyed nearly 200 oil and gas industry board-level directors, influencers and policymakers.

82 per cent of the 185 board-level directors and industry policy makers surveyed for the report are either highly or somewhat confident about the business outlook for their company, compared with 76 per cent last year. Just 8 per cent of those polled described themselves as pessimistic over performance in 2012.

Pekka Paasivaara, member of the GL Executive Board, said: “The second annual Economist Intelligence Unit oil and gas industry barometer sends a clear message: Companies are preparing to spend big in 2012, despite a slower growth in demand for oil and gas during the second half of last year, and concerns over the future of the global economy.”

Opportunities According to the report there has been a shift in the regions where companies see the greatest opportunities for revenue growth.

This year, the Middle East was placed in the top five, according to oil and gas executives, dropping two places since last year. North America tops the list, with the Far East (including China, Japan and Korea) placing second and Southeast Asia (including India) third. Last year, South-east Asia came top of the pile, with North America second, the Middle East and North Africa third and the Far East, fourth. The Far East (including China, Japan and Korea) has emerged as the key area for revenue growth, jumping three places from last year’s survey.

Upstream activities were the most popular choice for this question last year, and they have become even more heavily favoured this year, with the share of people selecting this option rising from 42 per cent to 56 per cent. Downstream activities are also expected to provide a stronger source of growth than last year, rising from 10 per cent to 14 per cent.

New energy politics The report touched on the implications from a year of turmoil in the Middle East and North Africa (MENA). The ongoing political unrest in the MENA region will have a long-term, rather than short-term impact on the oil and gas sector, according to oil and gas executives.

Increased security in key oil- and gas-producing areas is one obvious consequence for oil companies. “As of now we have 540 security consultants working for Schlumberger, 440 of these in Iraq. And I suspect we will have 100 in Libya by year-end,” says the chairman of Schlumberger, Andrew Gould.

However, the report also highlighted that the Arab Spring may offer growth opportunities through economic advancement.

“The Arab Spring will take time to settle, but it will bring with it a lot of opportunities because one reason it happened is that many of these countries have young, growing populations with rising expectations. You cannot contain those expectations – they have to be met,” said Carl Sheldon, chief executive officer, Abu Dhabi National Energy Corp.

Greater investment Increased optimism will feed through into capital spending increases according to the report. Findings from the research show that nearly two thirds (63 per cent) of executives plan to invest either somewhat or substantially more over the next year, in contrast to 49 per cent in 2011. 41 per cent of industry

18 Oil Review Middle East Issue Three 2012

Does your company plan to make more or less capital investment in dollar terms over the next 12 months? Select one. (% respondents)

2011:

16%

33%

33%

11%

4%

43%

22%

9%

3%

Invest somewhat less

Invest substantially less (At least 25% annual decrease)

2012:

20% Invest substantially more (At least 25% annual increase)

Invest somewhat more

Keep investment the same as before

Source: Economist Intelligence Unit Results showing respondents’ answers regarding capital investment

Middle East and North Africa drops down list of most promising regions for revenue growth in 2012 professionals expect to see increased investment in exploration activities over the next year, with only 4.3 per cent anticipating a decline.

The upstream remains the core focus for spending. A majority of respondents identify the upstream as the key area for business growth in 2012, meaning that exploration will be a major beneficiary of increased investment. Our survey shows that 41 per cent of industry professionals expect to see increased investment in exploration activities over the year, with only 4 per cent anticipating a decline.

The desire to invest also varies between companies. According to the report, majors like Shell are in active spending mode. The company has taken 16 new final investment decisions since the start of 2010 for more than 400,000 barrels of oil equivalent per day of new production. As spending ramps up on these and other projects, it expects that overall capital spending levels will increase as well. In general, Shell sees a robust demand outlook for oil and gas, and host governments and regulators are supportive of Shell’s plans to invest for new energy supplies. “The thinking tends to be long-term – many years or even decades in our industry, rather than driven by short-term factors,” says Shell’s chief financial officer, Simon Henry.

Meanwhile, many national oil companies (NOCs) also look likely to go on spending in 2012. But the report said that there is evidence of a more cautious

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S04 ORME 3 2012 Analysis 2_Layout 1 10/04/2012 11:45 Page 20

Analysis

Which sgment of the industry do you expect to see the strongest business growth in the next 12 months?

Select one. (% respondents)

approach in the Middle East. For example, Carl Sheldon, the CEO of Abu Dhabi National Energy Company (TAQA), sees the company spending US$2 billion in 2012, a small increase on the previous year: “Essentially we have a capital spending programme that started in 2010 and goes up to 2013.”

The overall message from the report is that for those plays where the economics are supportive, oil companies will continue to spend big in 2012.

There remains a big caveat, however: if global economic conditions were to worsen, oil and gas companies, whether big or small, would have to scale back their spending commitments in those areas where they can do so without creating damage to their wider portfolio.

“While capital expenditure looks set to take off, industry leaders will need to invest selectively this year, keeping operating risks low during a period of prolonged uncertainty. Their success will be defined by an ability to develop innovative approaches to operating more safely, efficiently and sustainably than ever,” said Paasivaara.

Hurdles Despite the more buoyant outlook for the oil and gas sector in 2012 if global economic conditions do deteriorate, oil and gas companies will have to scale back their spending commitments where they

2011:

42% Upstream

2012: 17% 10% 22% Midstream Downstream

Marketing

56% Upstream

12% 14% 8% Midstream Downstream

Marketing

Source: Economist Intelligence Unit

Results showing which oil and gas segment will see the biggest growth

A majority of respondents identify the upstream as the key area for business growth in 2012 can do so without creating damage to their wider portfolios, said the report.

Paasivaara added: “Findings from the report highlight a wealth of barriers to success, from rising operating costs to the worry of an impending shortage of skilled professionals and an uncertain regulatory environment in the post-Macondo era.”

Rising operating costs emerge as the main barrier to growth. When questioned in detail about costs, more than 50 per cent of respondents say

that they expect an increase in wages over the next 12 months. The second-biggest concern is the rising cost of contractors, with 54 per cent expecting costs to increase, compared with only 11 per cent anticipating a decline.

According to the EIU report, skills shortages are becoming more and more acute and this issue comes out of the survey as one of the major obstacles to growth over the next 12 months. Last year, skills issues came fifth on the list of barriers and were only identified as a top three issue by 25 per cent of respondents. This year, the issue has risen to second on the list, and has been identified as a key barrier by 34 per cent of respondents. n

Download the full report at: www.glnobledenton.com

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.

20 Oil Review Middle East Issue Three 2012

Honghua Golden Coast Equipment FZE. (Branch Company of Sichuan Honghua Petroleum Equipment Co., Ltd) P.O.Box. 261868 Jebel Ali Dubai-U.A.E. Tel: +009714 8807066 Fax:+009714 8807061 Website : www.hhcp.com.cn www.hh-gltd.com

S05 ORME 3 2012 E&P 1_Layout 1 10/04/2012 11:39 Page 21

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Heritage Oil spuds Miran East well

Aker Solutions wins drilling equipment deal

HERITAGE OIL REPORTED that drilling of the Miran East-1 exploration well in the Kurdistan region of Iraq has commenced with an estimated target depth of approximately 4,000 meters. This is the first well to be drilled on what the firm described as a highly prospective eastern structure, which has an area of approximately 130 sq-km.

The well is targeting exploration potential within the Cretaceous and Jurassic reservoir intervals of the eastern structure, contiguous with the hydrocarbon bearing Miran West structure.

The well design utilises recently acquired 3D seismic data and the enhanced understanding of the structural configuration within the Miran Field that this has provided.

Drilling of Miran East-1 is expected to take approximately seven months with multiple intervals to be evaluated and tested as the well is drilled.

"Our work program in Kurdistan continues with the spudding of the Miran East-1 exploration well. The large, undrilled Miran East structure has the potential to add significant hydrocarbon resources at all of the multiple reservoir intervals," said Heritage Chief Executive Officer Tony Buckingham.

The Miran Block has an area of 1,015 sq-km and is located west of the city of Suleimaniah. The Miran Block contains two large structures, Miran West and Miran East, which have been mapped from 2D and 3D seismic programs conducted by Heritage.

Heritage Energy Middle East, a wholly-owned subsidiary of Heritage, is the operator and holds a 75-per cent interest in the Miran Block and Genel Energy the remaining 25 per cent, although there are also third party back-in rights.

A SUBSIDIARY OF Honghua Holding of China has awarded Aker Solutions a contract to deliver high specification drilling equipment components for seven new onshore drilling rigs in the Middle East region.

The contract is valued at US$64mn.

Honghua is building a series of seven drilling rigs for a premier drilling company in the Middle East region. The contract includes options for another four identical deliveries.

Aker Solutions will deliver the first equipment sets to the customer in the fourth quarter of 2012. All equipment deliveries will be completed by the summer of 2013.

Each drilling equipment delivery includes a drawwork, three mud pumps, a 1,000 tonnes top drive and other equipment from Aker Solutions. The majority of the One of Aker Solutions top drives equipment will be delivered from Aker Solutions' subsidiary in Erkelenz, Germany.

"This contract underlines the quality of Aker Solutions' drilling equipment portfolio, combined with our proven execution ability on multi-rig projects and that our drilling expertise and high specification equipment can be applied in the onshore drilling market," says Thor Arne HĂĽverstad, executive vice president and head of drilling technologies in Aker Solutions.

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22 Oil Review Middle East Issue Three 2012

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S05 ORME 3 2012 E&P 1_Layout 1 05/04/2012 15:00 Page 23

Total acquires exploration license for Yemen operations TOTAL HAS ACQUIRED 40 per cent interest in the exploration license from Oil Search, which is subject to the approval of Yemen's Ministry of Oil and Mineral Resources. The license covers an area of 2,954 sqkm in the eastern section of the Marib Basin.

Total's partners will be the Austrian OMV, the Czech MND and state-owned Yemen General Corporation for Oil and Gas (YGC). Once the transaction has been completed, the joint-venture will resume exploration with a seismic survey which Detailed map of Yemen's oil blocks could be followed by a drilling of an exploration well.

Arnaud Breuillac, Senior Vice-President Middle East, Exploration & Production Total, commented today: "With this acquisition, Total is pursuing its strategy of expanding its exploration and production activities in Yemen, in high-potential geological basins that offer a close fit with existing projects".

Total's local production in Yemen has grown to 86,000 barrels of oil equivalent per day in 2011. The Group holds producing assets in the country's two main oil basins, as operator of East Shabwa Block 10 in the Masila Basin with a 28.57 per cent interest and as a partner with a 15 per cent stake in Jannah Block 5 in the Marib Basin.

In addition, Total participates in onshore exploration licenses through a 40 per cent interest in Blocks 69 and 71, and through operatorship of Blocks 70 and 72 with an interest of 50.1 per cent and 36 per cent respectively.

Third Badra well reactivated by Gazprom Neft GAZPROM NEFT ANNOUNCED that it had reactivated its third well, Bd1, at the Badra field located in Wassit Province in Eastern Iraq, the company said in a statement.

The Russian oil company is the operator at Badra field and the company said that “work will make it possible to determine the technical state of the well and subsequently test four productive strata at the site.”

Well Bd 1 is 5,000 meters deep. This is the third well at Badra that Gazprom Neft has started work on. The first appraisal well was drilled in November 2011, the second in January. Once investigation of the wells has been completed, the appraisal wells will become operational.

Three drilling rigs operate simultaneously on the site. During 2012 an additional four wells will be drilled, including a deep exploration well to study the lower strata at the deposit.

"The results of the drilling and seismic work carried out in 2011 will provide a better understanding of the site structure, and the final exploration plan will be drawn up in 2013," the company said.

The international consortium working on Badra oil field comprises Gazprom Neft (30 per cent), Korea’s Kogas (22.5 per cent), Petronas (15 per cent) and TPAO (7.5 per cent). The Iraqi Government, represented by the Iraqi Oil Exploration Company (OEC) retains 25 per cent.

The Badra development project is expected to last for 20 years with a fiveyear extension option. The calculated investment is expected to amount to about US$2 billion. Under the agreement, investors will be reimbursed for costs incurred and paid a bonus of US$5.50 per barrel of oil equivalent produced.

Badra oil field is estimated to have three billion barrels of oil in place. First production at the deposit is planned for 2013. By 2017 production is expected to reach 170,000 bpd (about 8.5 million tonnes per year) and maintain at this level for seven years. In total 17 operational and five injection wells will be drilled.

Oil Review Middle East Issue Three 2012 23

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S05 ORME 3 2012 E&P 1_Layout 1 10/04/2012 11:40 Page 24

Firms in Kirkuk oilfield upgrade talks

Iran’s oil output drops to a new low

BAKER HUGHES HAS joined BP and Schlumberger on separate talks with Iraq to more than double output from the country's giant Kirkuk oil field in northern Iraq.

"Baker Hughes, BP and Schlumberger have shown interest to develop Kirkuk oil fields," an Iraqi oil industry figure, who is familiar with the Kirkuk oil field, was reported

by Dow Jones Newswires as saying. "Iraq is conducting preliminary talks with these Map of Iraq’s main oilfields three companies to examine plans to develop the field," located in the Kirkuk province in northern Iraq.

Iraq is aiming to sign a five to 10 year deal with one of these firms to raise output from the field to 600,000 bpd from 280,000 bpd currently, the source added.

Production at Kirkuk has declined to 280,000 bpd from 900,000 bpd in the early 2000s after years of injecting water and dumping unwanted crude and products into the field.

Kirkuk oil field was one of the fields auctioned by Baghdad in the country's first oil licensing round held in 2009. A consortium led by Shell offered to boost output from the field to 825,000 bpd for a fee of US$7.89 a barrel, but Baghdad wanted payment of US$2 a barrel.

OIL PRODUCTION IN Iran dropped to a new low in February with crude output falling by 50,000 bpd to 3.38mn bpd, according to the International Energy Agency (IEA).

Western sanctions against Iran’s nuclear programme are really starting to bite and Iran’s hydrocarbon industry has already been suffering from years of underinvestment.

The IEA data for February revealed that Iran posted its lowest output level since late 2002. Late last year, the IEA forecast that Iranian production capacity would decline by 890,000 bpd to just under 3mn bpd by 2016 as a result of tighter sanctions.

Iranian Oil Minister Rostam Qasemi countered that the IEA's figures and estimates were incorrect and that neither production levels nor exports have fallen. Speaking in Kuwait recently, where he was attending the International Energy Forum, Qasemi stated that Iran is "exporting what we are supposed to within OPEC." There is the distinct possibility that Iranian output could fall even further this year. In its monthly market report, the IEA said that from July onwards when a European Union (EU) oil embargo comes into effect - Iranian exports could be cut by around 800,000 bpd to 1mn bpd, about a third of the current total.

"Iran will be casting around trying to find buyers for 800,000 to 1 million barrels," said David Fyfe, head of the IEA's market and industry division, adding that potential reductions in oil exports "could be much bigger than that."

The IEA based its figures on the 500,000-600,000 bpd of oil Iran exported to the EU before sanctions hit and the assumption that its other buyers would also scale back volumes in order to avoid breaching the sanctions.

24 Oil Review Middle East Issue Three 2012

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PH Petro completes EOR project in Oman PH PETRO HAS completed the single-well test project for Oman’s Daleel Petroleum Company which has delivered an impressive 134 per cent incremental oil gain.

The project marks the debut of SUR+ (Surfactant Plus) in the Middle East and PH Petro’s first foray into the region. PH Petro undertakes EOR projects in South East Asia from concept to completion and SUR+ has been field tested in more than 18 fields and 50 wells in various producing formation.

The recently completed project gauges the effectiveness of PH Petro’s surfactant technology in improving oil recovery at a Daleel producer well.

PH Petro’s SUR+ technology delivered 5,785 barrels of cumulative oil exceeding baseline forecast by 3,171 barrels of oil. Due to the favorable result, evaluation efforts are now underway to extend the EOR pilot flooding to cover several injectors and a few more IOR (improved oil recovery) at producer wells. The field implementation is forecasted to deliver incremental gain of between 100 to 300 per cent.

“Our test for Daleel has proven that our technology can increase oil recovery at a reasonable cost and in a very practical manner. This is a strong start to our Middle Eastern operations and we look forward to becoming the EOR provider of choice to some of the region’s top projects.

We would like take this opportunity to thank Daleel for its full confidence and support and anticipate a very productive partnership ahead,” said Fairuzz Nasron, President and Group CEO, PH Petro.

Daleel Petroleum Company LLC is a 50/50 joint venture between Mazoon Petrogas SAOC and Mazoon Petrogas BVI. It explores, appraises and processes hydrocarbon reserves in Oman’s Block 5 onshore field southwest of Muscat.

Seadrill agrees jack-up rig deal in Saudi SEADRILL HAS SIGNED a US$184mn contract with Saudi Aramco for the employment of its jack-up rig West Callisto offshore Saudi Arabia, a company statement said.

The contract duration is a minimum of three years plus an option for a one-year extension, Seadrill added.

The potential revenue for the The jack-up rig three-year period is approximately West Callisto US$164 mn plus a US$20mn mobilisation fee to cover various upgrades, dry tow vessel expenses and dayrate in the mobilisation period.

Alf Thorkildsen, CEO in Seadrill Management AS, commented: “We are delighted to have signed our first contract with Saudi Aramco for operation in Saudi Arabia. This award complements our growing jack-up operations in the region which will increase from two to five units this year.

We continue to see a strong demand for premium jack-up rigs and expect to improve our earnings visibility for this asset class going forward."

The West Callisto is currently operating in Southeast Asia and is scheduled to finalize its existing work scope in August 2012. The unit will subsequently commence its transit to the Middle East and is scheduled to start operations for Aramco in September 2012.

KNOC agrees further contracts with ADNOC

Gulf Keystone reveals Shaikan block results

KOREA NATIONAL OIL Corporation (KNOC) has signed a contract to develop three undeveloped oil blocks in Abu Dhabi with the Abu Dhabi National Oil Company (ADNOC).

Under the contract Korea One of the contracts is for will take a 40 per cent an offshore block interest in the fields (KNOC 34 per cent, GS Energy 6 per cent), with the remaining 60 per cent being held by ADNOC. The contract covers three undeveloped oil blocks, two onshore and one offshore, which have high exploration potential, the company said in a statement.

The combined oil initially in place for the blocks stands at 570mn barrels. The area covered by the blocks is 11,560km², one tenth of the Abu Dhabi area.

Development work will commence immediately with production expected to begin in the coming years. Oil production is expected to begin in 2014, if the development starts as planned later this month, and could rise to 43,000 bpd Commenting on the announcement, Hong Suk Woo, Minister of the Department of Knowledge Economy, said: “The contract between the governments of Korea and UAE are in three highly prospective areas and will allow Korea to secure up to an additional 570mn barrels of discovered petroleum initially in place."

This contract further strengthens the important relationship between both governments following last year's MoU for co-operation in the oil & gas sector.

GULF KEYSTONE PROVIDED an update on its ongoing exploration and appraisal program in the Shaikan block in Kurdistan Region of Iraq.

The Shaikan block is a major discovery with independently audited gross oil-in-place volumes of between 8 billion barrels to 13.4 billion barrels calculated on the P90 to P10 basis, with a mean value of 10.5 billion barrels.

The well testing program for the Shaikan-4 appraisal well remains ongoing, with six out of seven planned tests completed to date.

Portions of major intervals, such as the Kurre Chine, Butmah, Mus, Alan and Sargelu formations will continue to be tested and so far aggregate flow rates in excess of 14,000 barrels of oil equivalent per day ("boepd") have been achieved. Portions of the well that appear to be high quality oil reservoir on the electric logs, and where proven commercial flow rates were achieved by testing previous wells, will not be tested. The first five tests have been conducted in the northern "footwall" - on the lower side of the inclined fault bounding the Shaikan structure. This is the first occurrence of flow from the footwall and proves an extension of the Triassic and Jurassic reservoirs outside the central part of the structure. The latest test (Test 6) is being conducted in the "hanging wall" (the upper side of the inclined fault) from a new reservoir in the uppermost Sargelu formation which had not been previously flow tested. The test is ongoing and rates in excess of 4,000 boepd have been recorded.

After drilling the Shaikan-5 appraisal well to the depth of 1,876 meters in the Jurassic, it became necessary to drill a sidetrack due to a portion of the drill string becoming stuck in the hole. The sidetrack operations were successfully performed at the depth of 1,370 meters, after which the Shaikan-5 drilling operations have resumed below 1,730 meters, to continue drilling to the estimated total depth ("TD") of 3,500 meters, subject to technical conditions.

The Shaikan-6 appraisal well is currently drilling a 12.25" hole at the depth of 2,058 meters in the Jurassic. The well will drill to the estimated TD of 3,800 meters subject to technical conditions.

26 Oil Review Middle East Issue Three 2012

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Petrofac awarded Badra oil field deal in Iraq

Ukraine to invest in three Iranian oil fields

IRAQ AND A CONSORTIUM led by Russia's state oil producer Gazprom Neft has awarded Petrofac a US$329.7mn deal to develop the untapped Badra oil field in eastern Iraq. The field is located in Wasit governorate, 160km southeast of Baghdad, and extends across the border with Iran.

Ali Al Dabbagh said Petrofac would build a central processing facility for oil production in the field but he provided no further details, reported Dow Jones.

The consortium-also includes Korea Gas Corp.(Kogas), Turkish Petroleum Corp., or TPAO, and Malaysia's Petronas, The Badra oil field remains untapped so far is planning to start first production from the field by mid-2013, Gazprom Neft executives had said.

Gazprom Neft-operated consortium has started last year drilling in the field with estimated proven reserves of 3 billion barrels. It plans to drill some 11 wells in the fields in three years. Gazprom, which holds the largest stake in the consortium at 40 per cent, would receive along with its partners a payment of US$5.50 for each barrel extracted from the field as soon as the field reaches output of 15,000 barrels a day by mid-2013.

IRAN HAS SIGNED a contract with a consortium consisting of Iranian and Ukrainian companies for the development of Kouhmond, Boushkan and Kouhkaki oil fields.

The deal was signed between the Petroleum Engineering and Development Company, an affiliate of the National Iranian Oil Company (NIOC), and Inter Naft Gas Prom Pars Co., which is a consortium of Iranian and Ukrainian entities.

NIOC managing director, Ahmad Qalebani, was reported by the press that the consortium would invest about US$800mn in the development of the three Iranian oil fields.

Kouhmond heavy oil field is located 80 km to the east of Bushehr port in southern Iran. Though eight wells have been already drilled in the field, only two wells are meant for heavy oil production. The field's in-place heavy crude reserves have been estimated at about one billion barrels.

Kouhkaki oil field is located northeast of Kouhmond about 15 km south of the city of Khormoj. The field contains light crude with estimated in-place reserves of about 780 million barrels.

Boushkan oil field is located 100 km north of Bushehr and 30 km from Dalan gas field. The field's in-place reserves have been estimated at about 340mn barrels with a single well drilled in 1963.

The fields will be developed in two phases to produce 11,000 bpd of crude oil after the completion of the first phase, which will hit 22,000 bpd when the second phase is finished.

A total of 18 heavy and extra heavy oilfields have so far been discovered in Iran, including Ferdowsi oil field in Iraq, which is one of the country's biggest heavy oil fields with proven reserves of more than 31 billion barrels.

Iran holds the world's third largest proven oil reserves and the secondlargest natural gas reserves.

28 Oil Review Middle East Issue Three 2012

S07 ORME 3 2012 Gas_Layout 1 05/04/2012 15:25 Page 29

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Mubadala plans floating LNG terminal

in Fujairah M

UBADALA DEVELOPMENT CO. is working on a project that would use floating LNG storage and a regasification unit, the company said in a statement. The first supplies are expected in the next two to three years, it said.

Iran threatened earlier this year to close the Strait in response to sanctions that the US and Europe are imposing because of the Islamic republic's nuclear programme.

Offshore facilities

www.mubadala.ae

CASTR OL ULT IM A X C RIT IC AL PE R F

M

AN

CE

"The project would be outside the Strait, so that would give more supply security to ensure access to energy in the event of any incident in the Gulf," Robin Mills, an analyst at Manaar Energy Consulting in Dubai, said.

International Petroleum Investment Co. (Ipic), another fund run by the government, will also work on setting up the plant.

"Floating LNG plants are a very elegant solution" to fill the gap in energy supply for many Middle East oil producers, said Mills, a geologist who worked in Iran and the Middle East for a decade with Royal Dutch Shell.

OR

Gas

Abu Dhabi plans to build an import terminal for liquefied natural gas at Fujairah, a project that would enable vessels to supply the fuel without passing through the Strait of Hormuz.

S07 ORME 3 2012 Gas_Layout 1 05/04/2012 15:25 Page 31

Gas

"It makes sense because in this region many countries need LNG now and hope they'll be able to discover more gas in the future."

Offshore facilities can be moved once they are no longer needed and cost less to build than onshore sites. Middle Eastern oil producers such as Saudi Arabia and the UAE want additional gas supplies to make electricity and petrochemicals and as fuel for energy-intensive facilities such as smelters.

It makes sense because in this region many countries need LNG now Industrial expansion The UAE already imports gas from Qatar through the Dolphin Gas pipeline, a venture with Total and Occidental Petroleum Corp. The pipeline operates at about two-thirds of capacity because the UAE has been unable to buy additional fuel from Qatar, which has committed its supplies to other buyers.

The proposed Fujairah LNG terminal would be built in two phases, each having a capacity of 600mn standard cubic feet per day. The gas is needed to fuel industrial expansion in the UAE, a spokesman said.

Dolphin Energy Ltd., 51 per cent-owned by Mubadala, pumps about two billion cubic feet a day of gas from Qatar to the UAE and then on to Oman.

Importantly, the new LNG terminal being built in Fujairah's will be situated outside the Strait of Hormuz which has been the centre of attention over the last few months with Iran repeatedly threatening to close the major oil supply route.

Mubadala Oil & Gas has exploration and production interests in the Middle East, North Africa, and Central and Southeast Asia. Current working interest production is in excess of 400,000 barrels of oil equivalent per day. The

www.ipic.ae

company’s primary focus is on upstream oil and gas opportunities. It has been able to leverage the excellent commercial and governmental relationships that have been established over the years, both to facilitate the expansion of its operations, and to build capability in new regions including MENA, Central and South East Asia.

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32 Oil Review Middle East Issue Three 2012

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Gas

Bahrain in gas import talks BAHRAIN IS IN talks to import an average of 400mn cubic feet per day (cfd) of gas from Russia's Gazprom through a liquefied natural gas (LNG) terminal expected to open by 2015, the kingdom's energy minister said. Bahrain plans to initially import the equivalent of around three million tonnes a year of LNG but may buy more to meet soaring demand for energy in the kingdom.

www.gazprom.com

"Originally we would start off with say 400m cfd of gas and that could be slowly ramped up," Dr Abdulhussain Mirza said, adding the country was in talks with Gazprom about delivering it. Analysts say some of the LNG could come from as far away as northeast Russia but that Gazprom's growing LNG trading arm could source the fuel from anywhere.

Bahrain's gas import plans have long been hampered by political tension with regional producers Qatar and Iran and a looming gas shortage threatens the country's growth.

"Gas talks with Qatar have been postponed at the request of the Qatari authorities since 2006, since, a moratorium was imposed on future gas developments," said Dr Mirza.

Jordan and Iraq near agreement JORDANIAN AND IRAQI energy officials have entered advanced talks over a natural gas deal that would provide the Kingdom with an alternative energy source within five years.

According to Minister of Energy and Mineral Resources Quteiba Abu Qura, Amman and Baghdad are discussing "in detail" the terms of an energy agreement that would provide Jordan with sufficient natural gas to meet the majority of its electricity needs.

"We are studying this very closely, and we believe this is a very attractive option," Abu Qura told The Jordan Times.

The deal calls for the establishment of a 500-km gas pipeline stretching from Iraq's gas fields to the Kingdom's northern desert region, with a projected five-year construction period, according to the Ministry of Energy and Mineral Resurces.

The talks come amidst ongoing concerns over the reliability of Egyptian gas supplies, the Kingdom's primary energy source, which have yet to resume since a Sinai blast earlier this month that marked the 13th act of sabotage on the Arab Gas Pipeline in a little over a year.

In addition to Iraqi gas, Amman is exploring the possibility of importing Qatari liquid gas, to be stored aboard a ship in the Port of Aqaba ahead of the construction of a permanent offshore terminal on the Red Sea gulf, which energy officials say will take three years to build.

The rising costs of electricity production prompted energy officials to implement a nine per cent increase in electricity rates last month, but the government suspended the decision amidst a popular backlash.

Observers say the controversy over electricity prices has highlighted the growing importance of energy independence for Jordan, which imports 98 per cent of its energy needs at a cost of nearly one-fourth of the gross domestic product.

S07 ORME 3 2012 Gas_Layout 1 05/04/2012 15:25 Page 33

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S07 ORME 3 2012 Gas_Layout 1 05/04/2012 15:25 Page 34

Gas

Metering systems on the market METERING SYSTEMS FOR oil and gas are becoming increasingly important. As prices for petrol and natural gas have increased dramatically in the last ten years in Romania, companies such as Syscom 18 have seen an opportunity and started to engineer and manufacture metering systems for oil & gas companies. Most of the underground natural gas storage facilities in the country are measured by fiscal metering stations manufactured by Syscom 18.

These stations (bi-directional, using ultrasonic flow meters and turbines for verification, GCs for calorific power calculation) measure the natural gas accurately during the injection or extraction phase.

Quality metrological services have helped Syscom 18 win orders for natural gas metering stations on behalf of Romgaz, Transgaz and

Petrom, all large national oil and gas companies. Six years ago, new legislation in Romania meant tank farms had to install fiscal metering skids for all refined products.

“That was a good opportunity for Syscom 18 who became the largest Romanian manufacturer, having more than 200 skids installed in Romania, Iran, Kazakhstan, Libya and Jordan. Either mass or volume based, Syscom 18 has manufactured skids for all kinds of oil products, for trucks, wagons or pipelines. Syscom 18 was also the first Romanian company to receive MID (Measurement Instruments Directive) approval and we have invested in a new calibration facility in order to do complete tests and verifications in our own factory,” Mr. Ion Andronache, CEO of Syscom 18, explained.

Syscom 18 metering systems are already being used in some Arab countries

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S08 ORME 3 2012 Petrochems_Layout 1 05/04/2012 15:27 Page 35

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Petrochemicals

S08 ORME 3 2012 Petrochems_Layout 1 05/04/2012 15:27 Page 36

Securing natural gas feedstock in the Middle East has become increasingly difficult in the last few years, threatening the region's dominance as the most economical petrochemicals producer, according to a new report by business intelligence company GlobalData.

Feedstock costs determine the success of petrochemicals producers

Feedstock shortage threatens regional

producers T

HE NEW REPORT* found that the Middle East is now facing a natural gas scarcity due to increasing demand and inefficient utilisation of subsidized natural gas by the energy intensive industries, which has led to the restriction of supplies and posed a subsequent threat to the global petrochemical market.

Huge natural gas resources and cheaper feedstock availability turned the Middle East into the hub of the global petrochemical industry over the last decade by making the region the most competitive in the world. Middle Eastern petrochemical producers use natural gas as a key feedstock due to the availability of subsidies. This means that natural gas in Middle Eastern countries can be as much as 60-70 per cent cheaper than natural gas found in Europe and North America.

Scarcity However, the subsidies on natural gas production offered by countries such as Saudi Arabia, Iran and Qatar have led to the inefficient utilization of the available resources, leading to a decline in the supply of ethane feedstock. Feedstock costs determine the success of petrochemical producers,

as they represent the majority of production costs.

As natural gas is the primary feedstock used in the Middle East, its scarcity will affect the petrochemical producers significantly.

In addition, the Organization of Petroleum Exporting Countries (OPEC) quota limits crude oil production, thereby also limiting associated natural gas production. Despite all Gulf countries producing more than their allotted quota, production is insufficient to meet burgeoning demand from the power, transportation and petrochemical sectors.

Subsidies have led to the inefficient utilization of the available resources Saudi Aramco, the sole supplier of ethane in Saudi Arabia, stopped allocating ethane to new petrochemical projects in 2006, and pre-existing supply agreements have not received their allocated limits since 2009.

Lack of development of Iranian non-associated gas reserves has also led to the scarcity in ethane supplies, and Qatar have imposed a moratorium

upon further development of gas reserves, in order to assess sustainable rates of gas production, halting allocation of the country's gas for industrial projects until 2014. â–

*Petrochemical Industry - Key Geographies Experiencing Change in Feedstock Scenario The study provides an in-depth analysis of the petrochemical feedstock supply scenario in key locations, while explaining the reasons for a decrease in the supply of ethane feedstock in geographies such as the Middle East and Canada. It also explains the impact of new oil and gas discoveries on the petrochemicals industries in countries such as the US, Brazil and Canada. The study provides the basic petrochemicals (ethylene, propylene, butadiene, benzene, toluene, xylenes and methanol) capacity split by feedstock for all the five regions. The report highlights the change in the supply trend of petrochemical feedstock sources such as natural gas and crude oil. The report is built using data and information sourced from proprietary databases, primary and secondary research and inhouse analysis by GlobalData's research team of industry experts.

Graham Corp secures US$8mn orders GRAHAM CORPORATION, A designer and manufacturer of critical equipment for the oil refining, petrochemical and power industries, including the supply of components and raw materials to nuclear energy facilities, recently announced that it has secured US$8mn in orders that are expected to be delivered in Q4 of Graham's fiscal year 2013, which ends March 31, 2013.

The steam surface condensers for the Chinabased project will be used in a plant that produces

36 Oil Review Middle East Issue Three 2012

petroleum products from coal. As the world's largest producer and consumer of coal, China has embraced CTL technology. The petrochemical project in the Middle East is for an ethylene facility.

Petrochemical projects have been advancing with the gradual improvement in the global economy. All five steam surface condensers will be built in Graham's Batavia facility.

James R. Lines, Graham's President and Chief Executive Officer, commented, "Our bidding activity has been very active for oil refining, oil sands

upgrading, petrochemicals, and power generation, as well as renewable and nuclear energy projects.

As we see our pipeline of opportunities expand, it is very encouraging to have these projects, which have been in our pipeline for over a year, finally come to fruition.

"For both project wins, Graham's products, quality and track record of success were strongly preferred by the end user. We believe that our strong brand continues to enable us to win orders and maintain our leading market share."

S08 ORME 3 2012 Petrochems_Layout 1 05/04/2012 15:27 Page 37

Petrochemicals

S08 ORME 3 2012 Petrochems_Layout 1 05/04/2012 15:27 Page 38

Qapco awards contracts for ethylene plant QATAR PETROCHEMICAL COMPANY (QAPCO) has awarded Taiwanese company CTCI a US$165.9mn contract for the first phase revamp of its main ethylene production facility in Mesaieed Industrial City.

The contract value could rise in the future through additional optional requirements costing US$48.3mn making the total investment cost for Phase 1 come to US$214.2mn.

The contracts for Phase 1 were signed by QAPCO Vice Chairman & CEO Dr. Mohammed Yousef Al-Mulla, CTCI Chairman & CEO Mr. John T. Yu and IHI Vice President for Plant Engineering Operations Mr. Nitta Masami.

Phase 1 will see the installation of new furnaces and ethylene storage tanks. The project will utilise the latest technology in combustion, waste control and on-line monitoring. The main benefits would be direct and significant reduction in Nitrogen Oxides (NOx) emissions to the air, reuse of Coke inside the furnaces which will prevent soil and air contamination, better efficiency in fuel consumption and improved yield which will improve productivity and as a consequence reduce harmful waste, officials said. Phase II of the project, which is estimated to cost US$550mn, looks at increasing the

The signing ceremony for the Phase 1 contract

overall production to reach between 950,000 MT to one million tonne of ethylene. The second phase is still under study by QAPCO and its tender details will be issued after the approval by the company’s board.

Sabic agrees technology deal with Mitsui THE SAUDI BASIC Industries Corporation (Sabic) has signed a TDI (toluene diisocyanate) and MDI (methylene diphenyl diisocyanate) technology license agreement with Mitsui Chemicals.

Under the agreement, Mitsui will provide manufacturing technology for producing TDI and MDI, which are both raw materials for producing polyurethane. The agreement also provides for joint technology development in TDI/MDI, the company said.

The agreement was signed by Mohamed AlMady, Sabic vice chairman and CEO, and Toshikazu Tanaka, Mitsui Chemicals president

and CEO, at Sabic’s headquarters in Riyadh.

Al-Mady said the agreement will spearhead a strategic collaboration between the two companies to explore future possibilities to collaborate in the polyurethane (PU) business.

“The agreement will spur our strategic business plan to penetrate the global polyurethane market as well as power the ambition and competitive advantage of our customers for the long term,” he said. “It will also enable a fast development of PU application industries in Saudi Arabia, especially with regards to thermal insulation which will contribute to employment creation.”

“Through this technology license agreement, we will strengthen our product capabilities with high quality TDI and MDI and expand into the polyurethane business,” AlMady added.

Tanaka commented: “For Mitsui Chemicals, this license agreement will be the largest and most extensive one we have ever made. We will support this project full force on every front and are committed to its success. I hope that it will be just the first step in a future business partnership with Sabic, which may include establishment of a strategic supply base for competitive TDI/MDI.”

Total and KPC agree China refinery deal

Shell puts emphasis on integration

TOTAL SIGNED A Memorandum of Understanding (MoU) with Kuwait Petroleum International (KPI) and Petrochemicals Industries Company (PIC) to take a stake in the Zhanjiang refinery project in China.

Both companies are wholly owned subsidiaries of Kuwait Petroleum Corporation (KPC) and KPI, PIC and Total have agreed to form a consortium, which will potentially hold interests in two jointventures together with Sinopec.

The number of refineries in China is growing The MoU revolved around participating in the development of the 300,000 bpd full-conversion refinery integrated with petrochemicals and marketing, in partnership with Sinopec, Total said in a statement. The proposed refining and petrochemicals platform will be designed to process Kuwaiti crude as feedstock and to produce high-quality refined and petrochemicals products.

“KPC is pleased to expand its cooperation with Total” declared Mr Farouk Al Zanki, KPC Chief Executive Officer, after the signing of the MoU. “Total and KPC’s strategic objectives in Guangdong are highly aligned,” he added.

IAIN JOHN LO, Vice President New Business Development & Ventures, Shell Chemicals spoke to Oil Review about Shell Chemical’s strategy in the region and what the company’s key markets are.

Lo emphasised that Shell Chemicals does not want to get involved in everything as they want to remain focused on their own portfolio.

“We are a global business and we have a few derivatives which we believe are leading the market: including propylene oxide and Alpha olefins. We consider these as strong products," added Lo. Lo believes there is a general slowdown in feedstock demand due to the economic downturn, but claimed that Shell takes a long term view when working on large scale projects. “Fundamentally the outlook for the petrochemical industry is good,” said Lo. “Our geography is quite concentrated, we are in the US, Europe, Middle East (Saudi and recently Qatar), China and Singapore.”

Shell has been involved in Saudi Arabia with Saudi Basic Industries Corporation (SABIC), and since 1984 working on SADAF (Saudi Arabia Petrochemical Company) which is a long term project. Lo talked about the importance of cluster cities, like Jubail in Saudi and Ras Laffan in Qatar for the petrochemical industry to develop in the region.

Lo said Shell was looking towards Iraq in terms of petrochemicals.

“We have been awarded the Basra Gas Company contract, which is essentially gathering associated gas. But importantly within associated gas there is interesting feedstock. Clearly we are interested in building some synergies with petrochemicals.”

38 Oil Review Middle East Issue Three 2012

S08 ORME 3 2012 Petrochems_Layout 1 05/04/2012 15:27 Page 39

DONALD C CLARK, VP, Global Industry Solutions, Invensys Operations Management spoke to Oil Review about the value solutions his division brings to the upstream and downstream sector in the region.

Clark’s remit covers five heavy processing industries that include upstream oil and gas, chemicals, mining and power (fossil and nuclear). The team provides business strategies in the core global industrial markets.

Clark explained that Invensys will knit together solutions across their portfolio to deliver value.

He cited the example of the company’s work on brown fields in the region. The mature market is a one of the company’s focus and one particular play, even in this market, is brown fields which see Invensys taking existing assets and revitalising them. A great example of this is Invensys work on a 20 plus-year-old platform off Abu Dhabi. “We are helping modernise these platforms by improving their safety applications, improve their productivity. So we are upgrading the technology information of these platforms. With upgraded information services we can bring in optimised scheduling and we can effectively revitalise these

platforms,” he added.

In the downstream sector Invensys have provided three unique systems for refinery operations that are new to the market. One solution which has proved very popular is the energy management system. In a refinery you need a good balance of energy sinks and sources and to make sure it does not get out of sync which can lead to unscheduled shut downs.

“That is why we have solutions that look at the consuming and producing aspects in refinery and maintain the balance. The energy management solution comprises every piece of our portfolio, from sensors, information interface to data logging.”

“The other solution we are very excited about is refining optimisation. We are taking software programmes that essentially model the kinetic process going on in a crude unit, in a cracker and we are looking at the market price of the finished product. We run these programmes on a periodic basis and gives guidance to how you should optimally in terms of profitability set the parameters for the refinery. It is called Romeo.”

The third solution that Invensys is on the verge of introducing is based on our Triconex system.

It is a safety shutdown system and according to Clark it is a market leader. It is triply redundant which is unique. He provided the example of Saudi Aramco’s Ras Tanura which uses this system. It can provide analyses of each unit in a refinery and give a quantitative measurement of how safe they are operating. With this you can push certain units to operate at a high conversion rate because you know you are still safe. So you arrive at a real time assessment of the degree of safeness.

Clark concluded by talking about Invensys Net Oil and Wet Gas modeling-based system that measures the multiple phases and multiple components, liquids and vapors like water, oil and gas, in the same stream. This system is being used successfully in Algeria with state oil company Sonatrach. Due to the nature of the natural gas liquids in Algeria’s wells there is a need for a separator on top of most wells in the country. With the Wet Gas application there is no need to separate the gas and liquid on site and it can all be pumped to a central place without separation first.

Oil Review Middle East Issue Three 2012 39

Petrochemicals

Invensys’ value proposition

S08 ORME 3 2012 Petrochems_Layout 1 05/04/2012 15:27 Page 40

S09 ORME 3 2012 PDO Feature_Layout 1 05/04/2012 15:28 Page 41

Petroleum Development Oman’s (PDO’s) upstream engineers are meeting the challenge of complex reservoir systems and ageing fields head on to boost the nation’s oil and gas production year-by-year.

PDO Review

PDO delivers again with oil and gas

production boost O

MAN’S OIL AND gas reserves may not quite match those of fellow Gulf peer states but that has not stopped the Sultanate from making the most of what it does have. The country is still a major oil and gas exporter in its own right, though not a member of the Organisation of Petroleum Exporting Countries (OPEC).

At the helm, is the nation’s oil champion, Petroleum Development Oman (PDO), a joint venture that ties the government to various international investors, notably Shell.

PDO has long been the primary energy sector driver, accounting for the vast bulk of the country’s oil and gas production, though other foreign producers are also making a material contribution.

PDO continues to invest in the latest technology to help develop its meagre resources

And what a job PDO has done in recent years by turning around Oman’s dwindling production volumes, to restore output to former levels and pocket precious more income for the government as it continues to expand and diversify the economy beyond hydrocarbons.

Crucially, oil and gas production remains on an upward trajectory.

Oman’s average oil production increased 2.3 per cent last year to reach 884,900 barrels per day (bpd) in 2011, officials announced recently.

PDO’s widespread use of wide azimuth 3D data collection reflects a policy of using the most modern technology as it becomes commercially available

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S09 ORME 3 2012 PDO Feature_Layout 1 05/04/2012 15:28 Page 42

PDO Review

PDO’s engineers are rising to the challenge of complex projects such as Harwell

This is an incremental step up from 2010 when oil production totalled 864,600 bpd.

Average gas production also increased by some 4.4 per cent, rising to 95.1mn cubic metres (mcm) per day in 2011, compared to 91.1 mcm in 2010.

And the raised production was well rewarded too with higher oil market prices, averaging US$102.90 (Dh377) per barrel in 2011, up more 34 per cent from US$76.60 a barrel the previous year.

The production trend is up even though PDO’s own oil contribution slipped marginally, the result of labour unrest last year, among other factors.

The boost nets the government vital extra funds for economic development, at a time when there is added pressure across the region for social change and political reform.

For PDO itself, although it still maintains its status as the dominant producer in Oman, its oil output numbers slipped marginally from 553,000 bpd in 2011 to 549,280 bpd in 2011.

PDO’s managing director Raoul Restucci attributed the slip to lost work days through various factors including rain and labour stoppages, at the time of the so-called Arab Spring last year.

That said, combined oil, gas and condensate production in 2011 still reached its second highest level on record, at 1,206,000 barrels oil equivalent per day (boepd), underlining the continued strength of PDO’s production drive.

It is exceeded only by 2001 when group-wide production reached a record 1.21mn bpd.

Daily condensate production in 2011 stood at 93,600 bpd, while non-associated and associated gas production reached 463,000 and 85,000 barrels of oil equivalent (boe) respectively.

Restucci said the numbers remain consistent with PDO’s long-term oil production targets of 540,000-560,000 bpd, coupled with broad plans to expand gas output.

Reserve constraints The figures are equally impressive given the relative constraints that Oman must work to, notably its comparatively modest oil reserves.

According to BP’s 2011 statistical review, the country’s oil reserves stand at 5.5 billion barrels, just a fraction of those of its Gulf peers, while total gas reserves are estimated at 0.7 trillion cubic metres (tcm) (or 24.4 tcf).

Considering this number is less than half that of Kuwait (1.8 tcm), Oman’s gas exports -through the Oman LNG project - and production stand out as highly impressive.

The BP figures also chart the steady revival of Oman’s upstream production sector, spearheaded

by PDO, of course.

Oil production hit 865,000 bpd in 2010, according to BP, still way down on a decade ago oil output tallied 960,000 bpd in 2001 - but consistently up since the government took decisive action to stem the material decline witnessed early last decade.

From a low of 715,000 bpd in 2007, crude oil production has now climbed consistently every single year since.

42 Oil Review Middle East Issue Three 2012

Shift to unconventionals The production turnaround, for both Oman and PDO, has been made possible through sheer hard work.

According to Restucci, PDO’s high level of drilling and engineering activity has paid off.

This includes a successful 2011 in terms of exploration and reservoir development with a number of new potentially significant oil and gas opportunities and additions to reserves.

“While continuing to make conventional discoveries, our exploration emphasis in 2011 shifted to unconventional plays,” he said, highlighting the emergence of unconventional tight oil and basincentred gas opportunities.

The increased complexity of upstream operations, and a reliance on new technology through field development and recovery optimisation studies added 266mn barrels of oil reserves and 1 tcf of gas for a combined 450mn boe - to the group’s reserves.

The shift to unconventional plays is likely to take on more significance going forward, he reckons.

“Contrary to conventional discoveries, unconventional plays have greater potential, the scope and opportunity of which can dramatically change the supply landscape just as unconventional gas has changed the North American landscape,” said Restucci, in a February media briefing.

“Over the next few years, there will be an appraisal campaign to define the extent and distribution of the oil across the prospective areas, but confirming commerciality will only happen in later years, if appraisal and testing is successful.”

One example of early-stage technology uptake is the use of Time Frequency Electromagnetic Profiling, the latest innovation using electromagnetic signals to seek out hydrocarbons in underground reservoirs.

This technology was originally developed in China and is on trial by PDO in the Marmul area, the first time this technology is being used in the Middle East.

If successful, the technology could be utilised across PDO’s field operations.

Another technology being implemented by PDO, again as a first for the region, is a process known as hydrofrac monitoring.

The technique is based on lowering a number of geophones into an observation well to record microseismic events.

In effect, the technology listens to energy emissions that result when reservoir rock cracks, a natural process known as fracking.

By identifying the location of each frac, geologists can then identify the best place to drill their exploration and production wells.

In the second half of 2011, PDO performed the region’s first hydrofrac monitoring test in the Amin Tight Gas Reservoir Formation.

The trial was conducted in some extreme conditions, namely a 5,000 metre deep reservoir with a downhole temperature of around 175˚C. Results are currently being evaluated and a second test will take place in 2012 at the Khulud Field.

EOR leadership Technology drive As part of this effort, PDO continues to invest in its science and technology base.

Over the coming years, it intends to continue to invest in 3D seismic acquisition using state-of-the-art technology known as wide azimuth.

PDO started 3D seismic data acquisition using special seismic teams working round-the-clock in south Oman in early 2010.

Since then, it has acquired data covering over 7,500 sq-km, and during this year, will launch a major new seismic acquisition drive in north Oman’s alHuwaisa/Yibal area covering an area of 7,500 sq-km.

PDO’s widespread use of wide azimuth 3D data collection reflects a policy of using the most modern technology as it becomes commercially available.

It is increasingly keen to experiment with new pioneering technologies from the energy world.

PDO has also carved out a name for itself in the area of enhanced oil recovery (EOR).

In many fields, oil flow starts declining after less than 30 per cent of the reserves have been produced.

Maintaining the life of each field and ensuring maximum recovery is one of PDO’s strategic priorities.

In effect, each oilfield has to be individually nurtured by petroleum engineers with tailor-made strategies.

For example, the Marmul oilfield in south Oman has been producing oil since 1980.

By 2004, production had fallen by close to 40 per cent from its peak.

Since then, a series of interventions, starting with water injection, and more recently polymer injection, have resulted in a steady increase in the field’s overall production rates.

S09 ORME 3 2012 PDO Feature_Layout 1 05/04/2012 15:28 Page 43

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PDO Review

S09 ORME 3 2012 PDO Feature_Layout 1 05/04/2012 15:28 Page 44

Despite its age, the Marmul field is today producing more than ever before.

In such capital-intensive projects, PDO carries out intensive studies to ensure the right technology is chosen to maximise production flow from each field.

In many cases, small-scale field trials are carried out to make sure the chosen technology works in practice.

This includes fields such as Habhab in south Oman, where a trial was conducted in 2011.

The field, with an estimated 2.4 billion barrels of oil, was originally discovered in 1982, but the heavy nature of the crude means it has so far been impossible to produce.

PDO engineers are now busy trying to identify enhanced recovery solutions to unlock the oil from the field.

order to maintain pressure and enable wells to continue producing at stable rates over the next few years.

The Amin Infill and Water Injection Project involves the drilling of 118 horizontal producing wells and a further 35 vertical injection wells that will pump up to 70,000 cubic metres a day of water deep underground to help sustain oil production.

Water injection provides a cost-effective solution and gives PDO time to continue studying EOR that could be implemented in the years to come.

The Harweel challenge

In many cases, small-scale field trials are carried out to make sure the chosen technology works in practice

Amin development One example where engineers are already making a big difference is the Amin field, PDO’s seventh largest oilfield, with 1.2 billion barrels of oil in place.

Even though just 13 per cent of the oil has been produced, output has been falling, meaning there is plenty of potential for increased recovery if the right technology can be adopted.

Studies suggest that capital-intensive EOR technologies such as steam or polymer injection might not necessarily provide the best solution or value for money.

Instead, PDO is considering plans to inject water into underground aquifers below the reservoir in

Late in 2011, PDO achieved first production and first steam at the Qarn Alam steam project, another major EOR project.

Some 2,700 tons of steam is now being pumped into underground reservoirs at Qarn Alam, which will help release much of the heavy crude oil from the field.

Production will increase incrementally over time, and thanks to the steam injection, the field will reach a production plateau of 40,000 bpd of crude oil in 2015/2016.

New projects Keeping busy is how PDO has managed to maintain and improve its production profile steadily through recent years and this means consistently delivering on new projects.

“In fact, we need to bring on-stream at least one major new project a year if we are to continue achieving our long-term oil production target of 540,000 to 560,000 barrels per day,” said Restucci.

“At present, we have 750mn barrels of hydrocarbon resources under development across a number of major projects in the execution phase.”

In south Oman, PDO also continues to work towards the completion of what is probably its most complex and technologically ambitious project ever undertaken, the Harweel miscible gas project.

More akin to a chemical plant than a conventional oil facility, the Harweel plant was completed last year but pre-commissioning tests revealed anomalies in some critical equipment.

This equipment is now in the process of being repaired, and where necessary, replaced.

It means the plant is now expected to come onstream during the first half of this year.

PDO’s other steam injection project at Amal will see first production in 2013.

The project’s control room has already been completed and key equipment such as the steam generator and water treatment plant are already onsite.

These are all highly demanding and complex initiatives but PDO’s upstream engineers are rising to the challenge. ■

Omanisation drive PDO’S ROLE AS the sultanate’s largest company and national champion means it has a special responsibility to support employment and development opportunities for local Omanis.

During 2011, the company created close to 4,300 new jobs for local people while awarding 25 per cent of well engineering contracts to Omani-owned enterprises.

In the second half of last year, PDO developed the blueprint for a new ‘In-Country Value’ strategy, aimed at supporting local community companies, increasing the procurement of local goods and services, and improving domestic capacity and capabilities.

Key targets include: Doubling the number of skilled Omanis employed by the contracting community from the current 15 per cent to 30 per cent by Q3 2013.

Increasing the spending on in-country goods by US$100mn per annum with a target of 50 per cent of total spending on in-country goods by 2020.

Increasing the spending on in-country services by US$100mn per annum with a target of 75 per cent of total spending on in-country services by 2020.

As in other areas of the oil and gas business, PDO is determined to take the lead when it comes to making the nation’s energy sector work for the benefit of the whole country and its people.

Oman targets gas sector boost A KEY FOCUS for Oman right now is the development of its natural gas sector.

Already a major liquefied natural gas (LNG) producer, the country is keen to shore up new reserves and boost output, both for export use and for rising domestic consumption.

In the past decade or so, non associated gas production has shot up from next to nothing to closely trailing crude oil production, the nation’s biggest export earner.

PDO’s own gas directorate certainly had a busy 2011 delivering new projects.

The company is currently working to develop a brand new gas field in Lekhwair.

44 Oil Review Middle East Issue Three 2012

Site construction activities have already started and design contracts awarded.

The project involves construction of a gas processing facility that will treat an average of three million standard cubic metres per day of gas.

The project will comprise a single train in the Lekhwair gas plant for exporting gas to the Government Gas Plant in Yibal, while condensate will be delivered to the existing Lekhwair production station.

And as in the oil sector, work also included breathing new life into some of the nation’s ageing gas producing facilities.

Most gas flows naturally to surface, but over

time, it starts flowing at a slower rate.

To counteract the decline, PDO has turned to depletion compression, which uses powerful compressors to boost the recovery of gas from underground reservoirs.

There are two major upstream depletion compression projects currently underway.

The first, at Kauther, is almost complete and is scheduled for start-up during the second half of this year.

The second, at Saih Nihayda, is also well underway with major equipment already ordered and construction advancing ahead of schedule.

This project is well-placed for completion in the middle of 2013.

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PDO production levels soared in 2011 PDO'S 2011 PRODUCTION reached the second highest level in its history with production levels hitting 1,206,000 barrels oil equivalent per day (boe/d).

"PDO has delivered stable oil production and increased gas supply consistent with its short and long term objectives of providing a significant and sustainable energy and revenue stream for the benefit of the Omani national economy and its people," PDO Managing Director Raoul Restucci said at the company's Annual Media Briefing held in Muscat.

Daily oil and condensate production in 2011 stood at 549,280 and 93,600 barrels per day respectively and non-associated and associated gas production at 463,000 and 85,000 barrels of oil equivalent per day respectively.

PDO's exploration emphasis in 2011 shifted to unconventional plays.

Raoul highlighted the emergence of unconventional tight oil and basin centred gas opportunities. In addition, field development and recovery optimisation studies added 266mn zbarrels of oil reserves and 1 TCF of gas reserves (for a combined 450 million boe).

Raoul further added that "the extensive inventorisation and field development work has resulted in a Reserves Replacement Ratio (RRR) of 1.26, well in excess of 2011 production, while the encouraging unconventional results are expected to underpin longer-term production opportunities after extensive appraisal, testing and maturation work.

"Our work this year has laid the groundwork for sustained production and recovery optimisation," Raoul concluded.

A new safety milestone in Oman

Oil Review Middle East Issue Three 2012 45

PDO Review

No LTI on Oman land seismic project CGG VERITAS COMPLETED 20mn man hours of land seismic operations in Oman with PDO without a lost time incident (LTI). The company has a long term land acquisition crew, acquiring a very large high-density 3D seismic program in Oman. The crew is operated by CGGVeritas Middle East JV Ardiseis.

The crew has over 360 personnel and 130 vehicles. Field conditions include high desert temperatures and challenging terrain such as dense oilfield infrastructure, rocky wadis and steep jebels.

"We attribute such an impressive achievement to the commitment shown not only by the management, of both PDO and Ardiseis, but also by the field staff themselves," said Salim Al-Rawahi, Chief Geophysicist, PDO.

PDO Review

S10 ORME 3 2012 PDO News_Layout 1 05/04/2012 15:33 Page 46

PDO highlights importance of operational safety PDO’S LATEST ANNUAL media briefing discussed the pivotal role that operational safety plays for the company and how ensuring the personal and process safety of PDO people, contractors, and their assets is major challenge.

“It is extremely important that our staff and contractors work in safe conditions,” PDO stated.

PDO’s safety performance in 2011 recorded no work-related fatalities and a dramatic reduction in industrial-related lost time incidents, with the Lost Time Injury Frequency standing at 0.36.

The overall severity resulting from road traffic incidents has also shown improvements – mainly due to enforcement of PDO’s stringent driving standards and numerous road safety engagements held throughout PDO’s operations.

In total, PDO and its contractors have driven more than 429mn km without a work-related fatality.

Road traffic accident frequency Greater implementation of the In-Vehicle Monitoring System (IVMS) ensured more useful vehicles to alert drivers of impending hazards such as sharp bends data was collected on the driving habits of PDO drivers. With better and diversions. data, PDO safety teams were able to target drivers to help them PDO is determined to achieve Goal Zero, meaning no harm to people improve their safe driving skills. and the environment, and will continue to roll out new initiatives In addition, PDO is installing Personal Navigation Devices (PND) in its throughout 2012.

PDO signs major contract with SLCC PETROLEUM DEVELOPMENT OMAN (PDO) signed a major contract with Al Haditha Oilfield Services Company; one of five Super Local Community Contractors (SLCCs).

Al Haditha Oilfield Services Company will provide flowline replacement services.

The contract was signed by Ahmed bin Hamoud al-Dur'ei, Majlis A'Shura member; Representative of the Wilayat of Adam and Chairman of Al Haditha Oilfield Services Company's Board.

It was signed from PDO by Raoul Restucci, PDO's Managing Director.

The value of the contract totals US$35mn and will last for five years commencing on 1st June 2012. “The value of the contract will increase according to the scope of work al Haditha can cover,” added Restucci.

Al-Dur'ei said that the company will begin its works in replacing the flowline after two months from now in PDO's concession area in the north, starting from Jibal area via Khwair towards Fahud and Qarn Alam Restucci said that signing the contract comes as part of our "In Country Value" strategy, which

46 Oil Review Middle East Issue Three 2012

aims to support SLCC companies, and grow and develop products and services by Omani companies.

“Pioneered by PDO the ICV programme has now expanded to other upstream operators through OPAL who will coordinate the industry’s efforts under the auspices of a newly formed steering committee: “Oil & Gas In Country Value Committee” chaired by HE Nasser bin Khamis al Jashmi, Oil & Gas Undersecretary.

The five super LCCs (four of which are assigned to PDO) are part of an efforts to develope local communities in PDO’s concession area by providing them with business opportunities. Prior to the establishment of these super LCCS the share of PDO’s business to the local community contractors has been steadily increasing during the period 20082011 and exceeded $100 million in 2011.

“These local community contractors have grown, with increasing efficiency and competitive mindset and, in many cases, have become fully-fledged and experienced contractors competing in the local market,” said Restucci.

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PDO Review

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PDO’s technology push for the future PDO CONTINUES TO invest in 3D seismic acquisition using state-ofthe-art technology known as wide azimuth. PDO started 3D seismic data acquisition using special seismic teams working in south Oman in early 2010. Since then, PDO has acquired data covering over 7,500 sqkm, and in 2012, PDO will launch a major new seismic acquisition drive in north Oman’s Al Huwaisa/Yibal area covering an area of 7,500 sq-km, the company highlighted in its annual media briefing.

PDO’s widespread use of wide azimuth 3D data collection reflects a policy of using the most modern technology as and when it becomes commercially available. PDO sees itself as a regional pioneer in the development of new technology. One example of early-stage technology uptake is the use of what is called Time Frequency Electromagnetic Profiling, the latest innovation using electromagnetic signals to seek out hydrocarbons in underground reservoirs. This technology was

originally developed in China and is on trial by PDO in the Marmul area, the first time this technology will be used in the Middle East. If successful, the technology could be utilised across PDO’s operations.

Another technology being implemented by PDO, as a premier for this region, is a process known as hydrofrac monitoring. The technique is based on lowering a number of geophones into an observation well to record micro-seismic events. In effect, the technology listens to energy emissions that result when reservoir rock crack, a natural process known as fracking.

In the second half of 2011, PDO performed the region’s first hydrofrac monitoring test in the Amin Tight Gas Reservoir Formation. The trial was conducted in some extreme conditions, namely a 5,000 metre deep reservoir with a downhole temperature of around 175°C. Results are currently being evaluated and a second test will take place in 2012 at the Khulud field.

EOR Habhab field trial: update IN 2011 PDO conducted a small-scale field trial at the Habhab field in south Oman.

These studies help ensure that PDO picks the right technology before committing financial resources to implementing capital-intensive EOR projects.

An EOR project in Oman

The field with an estimated 2.4 billion barrels of oil was originally discovered in 1982, but the heavy nature of the crude meant that it was impossible at that time to produce. Today, petroleum engineers are working to identify enhanced recovery solutions.

As a first step, PDO engineers, working with local contractors, installed a temporary steam generating facility able to inject up to 130 tonnes of steam a day into the reservoir, 1,600 metres below the surface. Within a few days, oil was successfully brought to the surface. PDO’s petroleum engineering teams are currently evaluating results and progress with additional recovery and technologies are to be used for comparison and longer-term development selection.

PDO’s strong environmental commitment PDO HAS CONTINUED to work to ensure that it operates in an environmentally sustainable manner. PDO has claimed that 2011 was no exception. “We continued improving our energy efficiency in terms of the amount of gas used to fuel our operations,”the company said in its annual media briefing.

Despite the fact that PDO’s ageing oilfields are producing increasing amounts of water requiring additional energy for treatment and disposal, the amount of gas used for energy has actually fallen from around 12mn cu/m per day in 2005 to 8.4mn cu/m per day in 2011.

At Amal, where PDO is currently in the process of developing a major steam injection project, we have embarked on a pilot aimed at testing solar technology to generate steam during the day.

The 4-acre Solar Steam Generation Pilot that is in mobilisation phase will generate high-temperature, high-pressure steam using parabolic troughs housed inside agriculture-style greenhouses. The goal of the solar EOR project at Amal is to reduce the amount of natural gas burned for thermal EOR, releasing gas for higher value applications, including power generation, desalination, industrial development and export.

The Amal solar EOR facility will use concentrated thermal energy from the sun to produce low-cost, emission free-steam that will be fed directly into PDO’s existing steam distribution network. It is built specifically to withstand the harsh environmental conditions of the desert. Specially designed light-weight reflective mirrors are used to capture the sun’s rays and enclosed inside a glasshouse structure to protect the system from dirt, dust, sand, and humidity. If successful, the solar technology could be expanded to alternative applications throughout PDO’s operations.

48 Oil Review Middle East Issue Three 2012

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All is set for the opening of OGWA 2012 in Muscat on 16 April. The internationally renowned Society of Petroleum Engineers is organising a special technical conference on all aspects of enhanced oil recovery alongside

OGWA on track for

eighth edition A

RRANGEMENTS ARE COMPLETE for the eighth OGWA, Omanexpo’s Oil & Gas Refining & Petrochemicals Exhibition & Conference. All events take place in the Muscat IEC from 16-18 April, with the international Society of Petroleum Engineer’s Technical Conference (same dates precisely) held alongside at the Golden Tulip Hotel.

This year’s main OGWA exhibition theme is Fuelling your oil and gas markets with the Conference (content details below) focussing on Enhanced Oil Recovery/Building towards sustainable growth. OGWA 2010 attracted over 300 local and international companies showing an extensive range of products, services, equipment and technologies relevant to the Sultanate’s expanding energy plans, such as for the development of a large and completely integrated refinery and petrochemical complex in Duqm which is expected to attract further investment to the Sultanate as a whole.

Key development themes this year include

EOR techniques as a priority. The country’s premier oil and gas producer (by far) Petroleum Development Oman has once again signed a strategic partnership with Omanexpo for what promises to be one of the largest energy events in the region. PDO’s team of professionals will once again be supplying key technical input to the associated Conference, and will be prominent by their presence at the whole event, including numerous social functions.

With the support of the Oil & Gas Ministry and the Chamber of Commerce & Industry as well as leading operators such as PDO itself, Oman LNG and others a useful innovation this year will be the organisation of a special CEO Forum that will bring together leading business executives, policy makers and technical experts from energy companies worldwide, all in line with the Exhibition and Conference’s interlinked main themes as outlined above.

The OGWA forum

OGWA 2010 attracted over 300 local and international companies showing an extensive range of products, services, equipment and technologies

The OGWA forum, run by IIR Middle East, will bring forth the regions critical challenges and opportunities. These will be debated by top Middle Eastern oil and gas industry experts and policy makers at the Forum which will take place from 15 to 16 April.

With an emphasis on overcoming production challenges this new inclusion will provide a relaxed venue for reviewing and discussing a comprehensive range of the latest global developments and industry directions and an appropriate launching platform for further trade and business opportunities.

The forum, which will be attended by CEOs and senior managers from the major players, will also feature presentations from Zaid Khamis AlSiyabi, Director-General of Oil & Gas Exploration and Production at Oman’s Oil and Gas Ministry, and the GM of BP in Oman, Jonathon Evans.

Other highlights include Fareed Al-Asaly, Head of G20 Energy and WTO Groups at KSA’s Ministry of Petroleum and Mineral Resources discussing the role of alternative energy sources with Ivano Ivanelli of the Dubai Carbon Centre of Excellence and Vahid Fotuhi from BP.

SPE EOR Conference As well as providing a pair of focused training workshops for regional engineers (covering EOR geomechanics and Chemical understanding of EOR) the associated but independently organised, by the Society of Petroleum Engineers (SPE), EOR Conference will cover the following detailed aspects of what is now one of the oil and gas industries’ – mature operators anyway - hottest general topics; some subjects will be covered in more than one session:

www.ogwaexpo.com/

50 Oil Review Middle East Issue Three 2012

6 6 6 6

Chemical EOR Low salinity water flooding Thermal EOR Reservoir simulation

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6 6 6 6 6 6 6 6 6

Heavy oil Laboratory EOR Carbon dioxide Surveillance and monitoring Human capability requirements Technical/operational/economic challenges Gas injection of project implementation Well design Individual case studies

Major EOR projects currently being implemented in the Sultanate and likely to be reviewed at this separate event include a package of new facilities for the Amal Steam Surface Construction scheme, complete revamping of the Raysut terminal and the large Sohar Refinery expansion project, which will increase daily throughput capacity from 116 to 187,000 b/d, and output of naphtha as well. Other ongoing projects which loosely come under the EOR category include the massive Duqm development project outlined above, the Mukhaizna Thermal Flooding scheme, thermally assisted gas/oil gravity drainage at Qarn Alam, miscible gas injection at Harweel, and polymer flooding as an EOR technique (Marmul location).

Says Omanexpo’s General Manager Nasser Diab: “This alliance [with PDO] … comes at a time when there is a much greater need to boost the oil and gas industry in Oman. With PDO’s support of OGWA 2012 we achieve much easier our objectives of serving as an avenue to help meet rising sector demands as well as educate people about the present state of the industry.

“The oil and gas environment is getting more vibrant than ever, especially with the government’s ongoing projects … We provide a ready

www.spe.org/events/ogwa/2012/

platform to showcase petrochemical products arising from the refineries and will hopefully meet current local demand and further support exports.”

And added Mr Patrik Haliden, General Manager of a local global shipping and logistics business, after the doors had closed on OGWA 2010: “It was yet another opportunity for GAC Oman to be present in an event which attracted people connected with the oil and gas industry across the world.” ■ For full information visit www.ogwaexpo.com or call Omanexpo on +968 2466 0124 (info@omanexpo.com). For detailed information about the Technical Conference including speakers and timings visit www.spe.org/events/ogwa

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Oil Review Middle East Issue Three 2012 51

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Mott MacDonald’s strong track record in Oman MOTT MACDONALD has been present in Oman for 44 years and the UK based firm enjoys a strong track record of successful projects. Oil Review Middle East spoke to Vinod Shah, managing director of Mott MacDonald’s Oman business, about their presence at the forthcoming OGWA event in Muscat.

The Oil and Gas West Asia (OGWA) exhibition is one of the largest events of its kind in Oman. All the major oil companies will be represented and Shah believes OGWA 2012: “Will provide us with a great opportunity to showcase our skills and expertise and discuss the west Asia oil and gas sector.

Shah added: “We have been participating at this event for several years and given the positive outcome of previous years, we are excited to be participating once again.”

Mott MacDonald’s Oman operations began in 1968 and since then they have been providing the local oil and gas industry with their services while working with major IOCs and NOCs. “Although we enjoy a strong local presence and have a strong track record in Oman, the market has become very competitive since the country opened up to local and international oil and gas players. It is therefore crucial for us to have a presence at the show and reaffirm our commitment to Oman, which is what sets us apart in the competitive arena,” said Shah.

Mott MacDonald will be showcasing a number of

products/services at the show. In particular, the UK company will be showing its: “prestigious EOR projects recently delivered and demonstrate how implementing such technology can add new life to the oilfield by greatly improving its recovery factor and output. In addition, besides the traditional oil, gas and petrochemicals services and skills we are renowned for, we will show that being a global multidisciplinary company allows us to work in other key infrastructure areas such as water, transport, building, power, Vinod Shah, Managing Director at Mott MacDonald Oman and environment. We often draw from our multidisciplinary skills for the delivery of Shah concluded by talking about the outlook for the more complex projects,” stated Shah. oil and gas industry in Oman. “The outlook for the Mott MacDonald will be exhibiting at stand 101 and Oman economy looks good. The government has Shah encouraged anyone attending OGWA this year indicated an increase in the oil and gas budget and to come and visit to learn more about one of the plans to invest huge sums in the industry over the longest serving and experienced engineering next five years through a combination of consultancy firms in Oman. From early projects at government and private investment.”

Yibal and Fahud oilfields to more recent EOR “Our business in Oman is in very good shape and projects. They have had a long term relationship despite the strong competition from new and with Petroleum Development Oman as well as more international players we sustain a steady growth recent partnerships with other clients including Oxy, year on year. Last year we delivered an excellent Daleel, OGC, ORPC and OLNG. performance for the Group,” Shah added.

Oil Lift Technology prepares for OGWA DOVER MIDDLE EAST, an Omani company and subsidiary of the US company Dover Corporation, and Oil Lift Technology will be present at one of the largest oil and gas shows in the Middle East - OGWA in Muscat.

Dover Corporation acquired Oil Lift Technology in October last year that enabled the US company to expand its presence in progressive pump market.

Oil Lift Technology manufactures artificial lift systems for the oil and gas industry. It specialises in progressing cavity pump systems. Oil Lift products include wellhead drives, Rod-Lock BOPs©, progressing cavity pumps and remote power units.

Progressive cavity pumps are one of the fastest growing segments within the artificial lift market. Oil Lift products are used extensively in artificial lift applications around the world, and the company has developed a strong reputation for innovation and customer service that has enabled it to become a market leader.

Oil Lift employs over 150 people in facilities within Canada, the US, and Australia. The company has a strong international focus with significant activity in Latin America and the Middle East.

BP Oman to provide update on Khazzan Project BP OMAN IS exhibiting at OGWA 2012 and a focus of its presence is to talk about challenges and solutions in developing tight gas resources.

BP’s stand will describe the company’s approach to careers and skills development, to Omanisation, and to community investment. It also explains BP’s presence in the Middle East and gives the latest information about the Khazzan Project.

52 Oil Review Middle East Issue Three 2012

BP has been operating a pilot Extended Well Test at Khazzan since March 2011, helping to demonstrate the potential of a much larger scale development. BP’s pioneering work takes technology and expertise used to exploit challenging unconventional resources elsewhere and applies them to develop one of the Middle East’s largest tight gas accumulations.

The Khazzan and Makarem fields have gas in

place ranging from 70 to 130 trillion cubic feet.

The full field development of the resource, if it goes ahead, will involve drilling around 300 wells. The first phase of the project will target reserves of up to eight trillion cubic feet with first gas delivered in 2016. With full field development, BP would look to achieve production of around 1.2 billion cubic feet of gas per day – equivalent to about a 33 per cent increase in domestic supply.

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Continuing to expand in the Caspian THE 19TH INTERNATIONAL Caspian Oil & Gas Exhibition, incorporating refining and petrochemicals, will take place on 5th to 8th June 2012 in Baku, Azerbaijan. The Caspian Oil & Gas Conference, meanwhile, will be held at the Hilton Hotel, also in Baku, from the 6th to 7th June. The event serves as an annual meeting place for regional and international oil and gas leaders and representatives from the

www.caspianoil-gas.com

Ministry of Industry and Energy of Azerbaijan and the State Oil Company of the Azerbaijan Republic (SOCAR). The Caspian Oil & Gas Exhibition and Conference is held annually under the patronage of the President of the Azerbaijan Republic, HE Ilham Aliyev, and is also officially supported by the Ministry of Industry and Energy of Azerbaijan and SOCAR. Last year’s event saw the participation of 285 exhibitors from 30 countries and there were 5,166 visitors.

Azerbaijan has capitalised on its large hydrocarbon resources for over a decade now and has actively encouraged direct foreign investment in its oil and gas industry. This investment has revitalised the country’s oil sector through the development of large-scale projects and the refurbishment of existing facilities. With the completion of new pipelines, notably the BTC (Baku-Tbilisi-Ceyhan) and BTE (Baku-Tbilisi-Erzurum) pipelines, Azerbaijan has not only guaranteed secure routes to market for its oil and gas reserves but also positioned itself as one of the largest producers in the Caspian region and a potential transportation hub for other Caspian littoral states including Kazakhstan and Turkmenistan. The majority of oil production growth in Azerbaijan has been provided by the Azeri-Chirag-Guneshli (ACG) field while the majority of the country’s natural

gas is produced from offshore fields. The bulk of Azerbaijan’s future natural gas production is expected to come from the development of the large Shah Deniz offshore natural gas and condensate field.

The Caspian Oil & Gas Exhibition provides a platform for local and international oil and gas companies to display the latest technologies, developments in the regional energy sector and showcase current projects. The event has enjoyed an annual growth in show space and an increased level of participation by major international oil and gas companies. The Caspian Oil & Gas Conference provides a forum for international policy makers, representatives from the Ministry of Industry and Energy of Azerbaijan, international government representatives and leaders of commercial oil and gas companies to discuss the latest developments and market trends in the Caspian and Caucasus region. Over two days, plenary sessions and round-table discussions, organised in conjunction with SOCAR, will bring together around 500 delegates and over 50 speakers.

Canadian firms gearing up for ADIPEC ADIPEC 2012 will take place from 11-14 November 2012 at the Abu Dhabi National Exhibition Centre and is supported by key industry players such as ADNOC (Abu Dhabi National Oil Corporation) and the UAE Ministry of Energy.

Two thirds of the world's known oil reserves are concentrated in the region and Abu Dhabi plays a vital role in shaping the industry's development representing 95 per cent of total oil reserves of UAE making them one of the world's top five oil producing nations. The oil reserves in the UAE currently stand at 98 billion barrels and production stands at over 2.6mn bpd.

With an annual production at 50 billion cubic meters of natural gas, the UAE is the fourth largest owner of natural gas reserves in the world, possessing more than six trillion cubic meters.

In 2010, the exhibition was completely sold out with 1,502 companies taking part. Unprecedented international demand meant that the exhibition expanded from just 12 halls to include the concourse and outdoor exhibits as well.

Around US$4 billion worth of deals were signed during ADIPEC 2010, and over 41 per cent placed orders/purchased items not considered before attending ADIPEC. In addition, 27 per cent of visitors to ADIPEC had a budget of over US$ 1mn to spend at the show. According to the show organisers, visitors said ADIPEC was the place to source suppliers, and evaluate products/services from global markets. ADIPEC 2012 is an ideal venue for new-to-market firms interested in participating in the Middle East offshore and onshore gas development, as well as those seeking to promote their technologies and services to potential contractors and end users. ADIPEC is the largest oil and gas event in the Middle East and will once again play host to more than

30,000 visitors, 2,000 conference delegates and 1,500 exhibiting companies all under one roof for four days of dedicated networking.

In 2010, over 40 companies from Canada participated at ADIPEC. This year, there will once again be a Canadian Pavilion of 500 sqm. The cost for a fully constructed stand is CD$ 690 per sqm (minimum of 12 sqm) which will include a table, two chairs, three shelves, power, lighting, carpets, name board, and entry into the Canadian exhibitor directory.

For further information, www.adipec.com contact: Venky Rao 15-4135 Shipp Drive, Mississauga, ON, L4Z 0A7, Canada Tel: 1 905 896 7815 Email: venkyrao@rogers.com Imad Arafat, Trade Commissioner, Embassy of Canada .

Tel: +9712 6940334, email: imad.arafat@international.gc.ca website: www.international.gc.ca/abudhabi

Oil Review Middle East Issue Three 2012 55

Innovations

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First rigless ESP system installed ARTIFICIAL LIFT COMPANY, in collaboration with the Shoaibi Group, announced the successful installation of the first Rigless electrical submersible pump (ESP) string installed in the Middle East with Saudi Aramco.

The installation was performed in one of Saudi Aramco’s fields and comprised of a 134HP Rigless ESP system with a 6000 barrel-per-day pump. The system includes the Artificial Lift Company proprietary Permanent Magnet Motors and Wet Connect system. The unit was installed at a depth of 6,119 feet and included the installation of a downhole ESP gauge, packer, and subsurface safety valve assemblies.

Saudi Aramco has provided a platform for further installations throughout the Middle East with several operators already showing a desire to use this technology. Artificial Lift Company’s Rigless ESP technology provides an opportunity for clients to retrieve the ESP string without a rig, realizing significant benefits through cost savings on rig utilization and electricity expenditures, decreased downtime, and less oil deferment.

“Artificial Lift Company is honored to work with a company of such high caliber as Saudi Aramco, enabling them to achieve a level of optimization consistent with their production goals,” stated Alan Petrie, Business Development Manager, Saudi Arabia, for Artificial Lift Company.

“Technology like the ALC Advantage System (Rigless ESP Solution) and the ALC Accelerator System (Permanent Magnet Motors for tubing conveyed deployment), combined with quality and service excellence will profoundly transform how we produce ESP wells. The opportunity to partner with Saudi Aramco on this project, with continued support from Shoaibi Group, only furthers the impact that Artificial Lift Company is having in this important arena,” stated Alex Kosmala, CEO of Artificial Lift Company.

www.alcesp.com

The success of this installation follows closely on three wells in Alaska where the Artificial Lift Company installation team’s experience now establishes them as a global leader in providing Rigless ESP technology.

“This milestone installation validates Shoaibi Group’s ability to actively identify and invest in industry changing technologies that benefit energy providers across the MENA region. We look forward to continue supporting and providing ALC with all the necessary resources that will enable them to implement further successful installations across the Middle East,” stated Mark Jenkins, Shoaibi Group Director, and appointed ALC Board member.

H2S innovations reduce costs OIL AND GAS producers in the region are experiencing the challenges of producing resources laden with Hydrogen Sulfide (H2S) first hand. Working in this environment, companies must account for the increased risks to the safety of workers and corroding equipment in their project operating costs. Product recovery and flaring during well operations have a significant impact on the environment and are difficult to manage when H2S is present. AMGAS Services Inc. has created innovative ways to

www.am-gas.com

56 Oil Review Middle East Issue Three 2012

safely handle and process H2S. AMGAS offers a wide range of services, including H2S removal and control measures aimed at mitigating the dangers associated with processing sour oil and natural gas. The company’s team of professionals is trained in using the specialized and proprietary equipment, chemicals and processes.

“H2S is very dangerous, so the chemicals and equipment used must be dependable,” says January McKee, President of AMGAS Services Inc. “For AMGAS, dependable innovation has always meant that chemicals and equipment have been tested and proven to be reliable”.

Fluids containing H2S emit vapor equally as dangerous to workers and the environment. Treating the vapors requires dependable and innovative scrubbers to ensure the risks are eliminated and that the produced fluids can be stored, transported, processed or disposed. AMGAS has partnered with Rutledge E&P Pte Ltd. who provides service for upstream drilling and exploration activities.

Rutledge is based in Singapore and has operations throughout the Middle East.

AMGAS’s strategic partnership with Rutledge provides complete detection, protection and removal technologies for H2S environments. The Canadian based-company has over 25 years of experience working to reduce H2S and other noxious emissions.

Their scavenging and scrubbing chemicals are supported by personnel with the knowledge and experience necessary to reduce costs, environmental impact and increase safety.

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Innovations

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For oil and gas fire safety

Tank servicing alliance

PARADIGM FLOW SERVICES has launched an innovative system for cleaning safety critical fire mains in oil and gas installations. Pure-Flow can be injected into fire mains systems while pressurised, making it possible, for the first time, to deal with corrosion accumulation without shutting down operations.

Corrosion and marine growth in offshore fire mains is an industry-wide issue, particularly in ageing assets where the pipework can be more than 25 years old.

Paradigm has launched Pure-Flow to tackle corrosion caused by bacteria, which can restrict water flow, thin pipeline walls and also cause blockages in deluge nozzles. Pure-Flow is a practical-to-use chemical for the remediation of fire mains, and is also environmentally friendly. Using a pioneering deployment method, Paradigm can inject the chemical treatment and take debris from a live fire mains system whilst maintaining the system pressure.

Paradigm has developed a unique method of generating the chemical solution in-situ which is then injected into the live fire mains in low concentrations. The chemical then rapidly removes biofilm and marine growth deposits with no need for dismantling the pipework, as is the case in traditional methods of fire mains remediation, such as high pressure jetting. If there are instances where isolation vales don’t work, these would have to be removed and treated separately before treatment of the fire mains could commence. This new solution from Paradigm can be injected live into the system at any time throughout operations even where the ring main valves no longer isolate.

This provides a cost-effective solution as deluge and fire mains systems can be maintained online and even operated if required during the work. The PureFlow solution degrades quickly into sea-salt after use and is approved for use in environmentally sensitive areas.

STORAGE TANK AND gas holder specialist Motherwell Bridge is embarking on a ground-breaking alliance with professional services firm PROjEN and will become the first contractor to offer a complete suite of tank storage services from concept to handover. The firm leads some of the most high profile tank and refinery projects across the UK, Europe, Middle East and Africa and the tie-up with PROjEN will allow Motherwell Bridge to offer process design, engineering and management expertise for new-build or remedial tank works without the need for separate project managers.

Specialising in project management and professional services, PROjEN’s alliance with Motherwell Bridge brings a collaborative approach which emphasises forward planning, scope definition and risk management.

The revolutionary collaboration combines Motherwell Bridge’s reputation for in-house design, refurbishment and new build on large diameter tanks with PROjEN’s project management and multi-disciplined engineering expertise to provide efficient A-Z project implementation.

ITT announces global supply agreement

Offshore automation contract awarded

ITT CORPORATION ANNOUNCED an Enterprise Framework Agreement with Shell Global Solutions in which ITT's Goulds Pumps brand will provide American Petroleum Institute (API) centrifugal pumps to support Shell operations worldwide.

Shell Global Solutions is part of the Shell Group, a global leader in the energy and petrochemical markets.

Under the agreement, Goulds Pumps, a leading product brand of ITT and a leader in API pumps, will supply these pumps in several configurations to Shell operations and affiliates worldwide. The Enterprise Framework Agreement is for five years with an option for www.itt.com an additional five years.

Shell applied a comprehensive process in selecting ITT Goulds Pumps, and this agreement includes the development of common specifications, terms and conditions, and pricing. The Goulds Pumps brand is part of ITT's Industrial Process business, a dynamic business that is growing and expanding globally and has an extensive portfolio of leading-edge technology that has served customers in the oil and gas, mining, chemical, power generation, biopharmaceutical, and general industries markets for more than 160 years.

KONGSBERG MARITIME HAS been awarded a significant offshore automation contract with Daewoo Shipbuilding & Marine Engineering (DSME). The contract covers the delivery of Kongsberg Maritime’s proven Dynamic Positioning, thruster control, bridge navigation, vessel automation, safety, riser management and environmental monitoring systems to two semi-submersible drilling rigs (Cat-D).

The two new build high specification semi-submersibles are designed for mid-water harsh environment in the Norwegian North Sea and have been orderd by Songa Offshore SE subsidiary, Songa Rig AS, following a Letter of Award (LOA) from Statoil.

"This is what we call a 'Full Picture' solution from Kongsberg Maritime. Our strategy is to take on more responsibility in the value chain by offering a full range of Integrated Automated Marine Systems. This contract was won as a direct result of this approach.

Close collaboration with the customer and a commitment to understanding the extreme contexts in which our technology is applied are important driving forces behind this award," said Geir Håøy, President, Kongsberg Maritime.

Kongsberg Maritime will commence deliveries, including engineering services, to the DSME yard in Korea early 2012, with all key Kongsberg Maritime deliveries scheduled for completion by December 2012.

Startup, commissioning and trials are scheduled to be completed in Q1 and Q3 2014. The contract also comes with an option for Kongsberg Maritime to deliver products and services for two more semi-submersible drilling rigs.

"The competition is strong and we are very pleased to have secured this contract. It is a clear demonstration of our capabilities in this field. I am also very pleased with the hard work performed by our international offshore team," concludes Tor Erik Sørensen, Executive Vice President, Kongsberg Maritime.

58 Oil Review Middle East Issue Three 2012

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Fixed-cost ‘taster kits’ QUICKFLANGE, ONE OF the industry’s leading providers of high performance pipe connection systems, is to launch a series of fixed cost ‘taster kits’ designed to stimulate initial use of its own ‘cold’ pipe connection solution the Quickflange.

The new taster kits, which are being launched in the UK and the Netherlands and which will be priced based on each installed flange, will allow operators to see the benefits of the Quickflange for themselves before making any longer-term commitments.

Furthermore, operators will also be safe in the knowledge that there will be no additional costs from open-ended mobilisation or if a particular job is delayed or moved. Such delays can be particularly expensive with additional costs relating to rental equipment and increased personnel requirements. The Quickflange pipe connection solution provides a fast, convenient, safe and highly cost effective piping solution equivalent in strength to a welded or mechanical connection. As it takes place within a ‘cold-solutions’ environment, the Quickflange solution doesn’t require heat sources in the same way that welding does.

A key component INDUSTRIAL SCIENTIFIC, A leader in gas detection as a service, announced the availability of the Ventis™ LS multi-gas detector as part of the Accenture Life Safety Solution. Using Wi-Fi and location-based technologies to remotely monitor those working in potentially hazardous environments, this wireless solution helps keep people safer.

The Accenture Life Safety Solution leverages the expertise of Industrial Scientific, as well as their unique Gas Detection as a Service solution known as iNet®.

It also incorporates the leading technologies and processes of Accenture, AeroScout and Cisco. The solution is designed to continuously monitor employees working in plant environments across oil & gas, chemicals, petrochemicals, metals, mining, forest products and utilities.

The Ventis LS has the ability to detect one to four gases, including H2S, O2, LEL, CO, SO2 and NO2. In potentially hazardous conditions, the instrument alerts users through audible, visual and vibrating alarms.

The instrument’s gas level information is then transmitted over Cisco’s Unified Wireless Network using the gas detector’s integrated Wi-Fi Tag from AeroScout.

60 Oil Review Middle East Issue Three 2012

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Innovations

S12 ORME 3 2012 Innovs 1_Layout 1 05/04/2012 15:43 Page 62

UniQ System available to all OIL REVIEW COVERED the launch of WesternGeco’s new UniQ* System Sales division and heard from Sanjay Singhal, Vice President, and Boff Anderson, Business Development Manager, about the significance of the new service.

WesternGeco announced the formation of a new division to sell and lease its UniQ point-receiver land acquisition and processing system to other industry players.

The announcement was made at a special launch event during Geo2012 in Bahrain. Sanjay Singhal opened by saying that the launch of the system sales division will usher in "a new era in the land seismic service industry."

Khalid Mugharbel, President of Schlumberger Middle East, was also present at the launch saying WesternGeco was launching: “a major new business model here in Bahrain.”

He added: “WesternGeco has spent over twenty years building its point-receiver approach, particularly in the Middle East and we have seen that it offers drastically better efficiency, productivity and ultimately seismic imaging and resolution.”

Benefits Boff Anderson, Business Development Manager for UniQ product line, was at the launch to guide people through the main features and key benefits of the UniQ system.

“UniQ is the only purpose built high channel count, high productivity point-receiver system on the market,” said Anderson.

UniQ technology has been designed from the ground up and offers better seismic imaging through denser noise and signal sampling. The UniQ platform is designed as an open-architecture system with a capacity in excess of 200,000 channels and forms an auto-correcting, fault-tolerant layout that maximises uptime and efficiency.

“UniQ is a continuous recording system and the high channel capability means that our customers can lay out large super spreads.

UniQ can also handle any type of simultaneous and high-productivity source techniques, which makes these denser geometries cost effective.”

The UniQ central acquisition system architecture is optimised to meet the challenges of high-channel count, high-productivity acquisition. The central system functionality enables continuous domain quality control of seismic data and equipment status, as well as real-time monitoring of sensor tilt and cable leakage.

The UniQ system

The integrated source control (ISC) system is an enhanced timing and communications solution that integrates current third party source controllers with the UniQ central system to deliver enhanced timing, productivity and quality control functionality.

WesternGeco currently has the system up and running with 105,000 channels. “It is a live system in operation today,” said Anderson.

Anderson outlined a number of benefits that the UniQ system can bring to a survey.

Time is always a key factor in any project and UniQ can help reduce the time spent on a survey and thus in turn reduce the E&P cycle time, which can thus reduce overall costs.

Any new data has to bring additional value and “UniQ can deliver much better quality data in a given timeframe.” Better quality data can result in improved decisions in an exploration development cycle.

Ideally suited “Less time spent on a survey will lead to reduced Health, Safety and Environment (HSE) risk and better decision making from better quality data will also lead to reduced Exploration and Production risk as well,” reasoned Anderson.

Anderson believes that market trends driving the industry are changing and that there is a renewed emphasis on exploration and increasingly more complex reservoirs needing to be resolved.

“We can see that the industry is moving towards high channel counts for better signal sampling and high productivity source techniques for a more cost effective service,” said Anderson Depth imaging is also becoming a standard and “we will see that the ground roll, traditionally seen as noise, but recorded faithfully by pointreceivers is actually signal with important information to help derive a better characterisation of the near surface, which then helps deliver a more accurate velocity model.”

“This is where we believe that the UniQ system is ideally suited to meeting these needs of the industry,” Anderson added.

Challenges With industry adoption of high-capacity point-receiver seismic technology accelerating, open availability of the UniQ system is expected to lead to further growth.

“WesternGeco’s decision to make their UniQ system available to anyone is to be welcomed of course and as customers we know you want to see increased competition,” Mugharbel said.

Anderson explained that WesternGeco was making the system available to the industry to accelerate the uptake of pointreceiver acquisition technology and also to help realise the value of our investment by having it more widely implemented.

UniQ will be fully supported by Schlumberger’s research and engineering organisation, which will ensure that UniQ will be able to deal with all future challenges.

“UniQ technology is more than an acquisition system and we will also be making all of the spread design, data management and single-sensor noise reduction and signal enhancement software available,” said Carl Trowell, president, WesternGeco.

*Mark of Schlumberger

62 Oil Review Middle East Issue Three 2012

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Innovations

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Innovative survey and inspection platform CAOMM HAS ANNOUNCED that it will be making a bespoke, remotely-operated underwater survey and inspection platform available to the Middle East market.

Following identification of a requirement for an integrated vehicle to perform survey and inspection of assorted assets from depths of up to 100m, through the intertidal zone to drying heights, Offshore Marine Management have conceived a unique approach to a problem which would usually require the deployment of multiple conventional ROV and diving spreads.

CAOMM has been created from a joint venture between Controls and Applications Emirates (CAE) and Offshore Marine Management (OMM).

OMM has approached this problem from the perspective of a customer who wishes to minimise not only project costs but also risks.

This, coupled with the ethos of producing a solution that is tailored to the task rather than employing an existing underutilised asset, has led OMM to develop an integrated vehicle which is capable of working both dry and submerged.

The vehicle is a four wheel drive, all terrain crawler which acts as a platform for conventional survey sensors and also has the facility to carry an onboard ROV. With full

independent suspension supporting each drive system, the crawler is designed to provide the optimum platform for the onboard sensors.

These will be used to track and survey both route corridors as well as fixed assets, including pipelines and cables. The ROV is also available to be remotely deployed for additional inspection of hazards, areas of particular interest or offshore installations which can be reached in a single journey from the shore.

Accurate positioning of the combined system is achieved using multiple technologies which ensure continuous navigation data is available, even through the harsh intertidal zone.

Rigorous design criteria were developed and adhered to during development, ensuring that the crawler platform will be capable of working in currents in excess of three knots, across all types of seabed terrain from soft sands, subsea obstacles to bedrock and up to 40° slopes.

System deployment to point of mobilisation will be achieved using a single HGV. From there, it may be loaded onto any vessel of opportunity from a multicat to a DP 2 vessel.

Use of a crane based LARS ensures little or no modification of a host vessel is required, whilst control and monitoring will be undertaken

from a standard ROV control van. The platform will be operated using a bespoke software system which will provide both ROV and crawler control.

The all inclusive capabilities of this single package are designed to offer customers significant cost savings when compared with the use of multiple conventional packages to meet the survey and inspection requirements of key assets.

With flexibility being a keystone of the design specification, positive feedback has already been received from Energy and Telecommunications customers. The system is scheduled for delivery in 2012 and, commenting on the development, OMM’s Director of Survey & Subsea, Arron Burrows said: “Importantly, this hybrid solution will remove the need for multiple vehicle mobilisations as is currently commonplace in the offshore environment. We believe that many operators will therefore see this as a cost-effective solution, avoiding the need for additional equipment and personnel. It will also be small enough to be easily-transported within a multicat or dynamic-positioning (DP) vessel, yet remains highly adaptable and high-powered.”

Trelleborg on show at OTC

Solutions for automated flow control

TRELLEBORG WILL SHOWCASE its extensive product portfolio at the 2012 Offshore Technology Conference in Houston this year.

Emphasizing its product and material engineering focus, Trelleborg will give six presentations at the company’s booth (No. 5217) during the show.

Trelleborg Sealing Solutions is one of the world’s leading developers, manufacturers and suppliers of precision seals and bearings.

Trelleborg’s sealing systems for the oil and gas industries are www.trelleborg.com designed to cope with high-pressure, chemically hostile environments. Its products include O-Rings, gaskets, hydraulic seals, rotary shaft seals, static seals, oil seals and pneumatic seals. Trelleborg Sealing Solutions will officially release its comprehensive, all-new Oil & Gas Product Catalogue & Engineering Guide at the conference. Trelleborg Oil & Marine Hoses is a leading supplier of innovative and field proven large-bore bonded hoses for crude oil, chemicals, LPG and LNG marine transfer solutions. The company provides full service worldwide through the whole life cycle of the product – engineering studies, delivery of complete solutions (hoses and ancillary equipment), on-site supervision and recommendations for installation, maintenance and repairs.

THE RECENTLY OPENED Botlek Tank Terminal (BTT) at Rotterdam relies on Rotork’s latest electric valve actuation technologies for automated flow control and vital safety related duties associated with the import, export and storage of a varied range of liquid bulk products. Construction of the first phase of the terminal began in April 2010 and was completed within budget and on time by the Polish company Polimex-Mostostal S.A. BTT has 34 storage tanks, providing a combined storage capacity of 200,000 cubic metres, of which 130,000 cubic metres is earmarked for clean fuels and the rest is for edible oils and biodiesel. The state-of-the-art terminal has deepwater berths including a 420 metre jetty that can simultaneously accommodate two seagoing vessels and two barges, operating 24 hours-a-day.

Over 250 Rotork IQPro multi-turn and quarter-turn intelligent electric actuators have been installed to operate the valves that control the routine movement of liquids throughout the site. A further 55 Rotork Skilmatic SI self-contained electro-hydraulic actuators have been installed in strategic areas on valves that provide failsafe Emergency Shutdown (ESD) protection from potential accidents and spillages. All the Rotork actuators are monitored and controlled on fully redundant Rotork Pakscan digital bus loops, linked by three Pakscan P3 master stations to the site’s central SCADA system.

The Skilmatic SI actuators are equipped with integral circuitry designed to receive a separately hardwired discrete ESD alarm signal that will override any other input and move the actuator to the pre-determined safe position, even in the event of electrical power failure. These actuators are situated on the inlet and outlet ports of the storage tanks and on the marine and truck loading bays.

They are key components in the Safety Instrumented System (SIS) that operates with dedicated level and flow sensors and ESD logic solvers to provide the site’s Safety Instrumented Function (SIF).

64 Oil Review Middle East Issue Three 2012

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005

Innovations

S13 ORME 3 2012 Innovs 2_Layout 1 05/04/2012 15:46 Page 66

Delivering reliable analysis

Qatar contract for Unique Wellube

SCHLUMBERGER ANNOUNCED THE availability of its new PressureXpress-HT* reservoir pressure service and MDT Forte-HT* qualified, rugged, high-temperature formation sampling and pressure system. These two services are the latest hightemperature additions to the Schlumberger reservoir characterization portfolio of services. “Providing a full suite of high-pressure, high-temperature (HPHT) evaluation tools is a major engineering focus within Schlumberger. These two tool systems expand our capabilities to deliver reliable downhole fluid analysis, fluid sampling, pressure measurement and interval pressure transient testing,� said Catherine MacGregor, president, Schlumberger Wireline. Rated to 450°F the PressureXpress-HT tool provides accurate pressure gradients and www.slb.com overall data quality not achievable by conventional high-temperature formation tester tools. The unique dynamically controlled pressure pretest system in the PressureXpress-HT tool enables precise control of volume and drawdown rates. This now makes pressure testing possible in tight formations common in HPHT reservoirs. The tool design also eliminates the need for gauge temperature stabilization, thus significantly improving overall operational efficiency.

UNIQUE WELLUBE, A Unique Maritime Group Company which is one of the world’s leading integrated turnkey subsea and offshore solution providers announced the winning of a three-year contract from Qatar Fuel additives Co. Ltd. for Online Leak Sealing Services.

The contract includes the provision of suitably qualified engineers fully trained in Under Pressure Leak Sealing Procedures and methods on pressurized piping systems, and additionally to provide all necessary service equipment to perform Leak Sealing Service in Qatar.

Graham McKay, International Business Development Director of Unique Wellube commented on this contract saying “We are very pleased with this opportunity to work with QAFAC and will ensure we meet their expectations with high quality products and service�. “We are always very careful in selecting our suppliers and are pleased to award this contract to Unique Wellube. We look forward working with them and building a long lasting business relationship too� said Hussam H. Al-Natour who is head of Procurement at QAFAC. Unique Wellube FZC are providers of specialist engineering services and products to a diverse range of industries. The company’s range of services is directed at maintaining plant operability, by allowing intervention work to be carried out with the minimum loss of production, in a safe and cost efficient manner.

Utilising many years of combined experience, Unique Wellube’s team of professional graduate engineers and highly skilled technicians utilise operational experience backed by substantial R&D, to provide innovative solutions to meet its customers’ most demanding challenges.

A leading designer and manufacturer of bespoke metering, hydraulic control systems and produced water treatment solutions

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www.alderley.com www .ald derley.com 66 Oil Review Middle East Issue Three 2012

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Pipeline inspection services BAKER HUGHES HAS broadened its pipeline service portfolio to include circumferential magnetic flux leakage (MFL) inspection technology, which enables pipeline operators to identify anomalies www.bakerhughes.com in pipeline long seams and more effectively manage the risk associated with cracks in long seam welds and the overall integrity of their pipeline assets.

The company recently acquired the assets and circumferential/transverse field (TFI) MFL technology of Intratech Inline Inspection Services Ltd. With circumferential MFL inspection technology, Baker Hughes Process and Pipeline Services group can assist operators with locating specific pipeline seam threats, such as hook cracks, lack of fusion and long narrow-axial corrosion. The circumferential MFL technology will now be produced in the larger diameter pipeline sizes, complete with speed control and inertial navigation capabilities.

Anti-corrosive coatings LEVERAGING CROSS-INDUSTRY KNOWLEDGE and experience to deliver optimal anticorrosive coatings, Jotun claims to have widened the technology gap with Jotamastic 90 - a step change in high-tech surface tolerant coating solutions.

The new Jotamastic 90 is one of the most technologically advanced surface tolerant repair and maintenance primers in the market.

Jotamastic 90 is a highly durable coating featuring benefits such as exceptional corrosion resistance, shorter overcoating intervals, wider top coat compatibility and increased colour flexibility using Jotun's Multi Colour Industry (MCI) tinting system.

Jotamastic 90 has exceptional corrosion resistance and is suitable for the most severe environments. It has reduced drying time by up to 40 per cent compared to existing products, thus reducing downtime and overcoating intervals.

Jotamastic 90 offers compatibility with most topcoats, including polysiloxanes and two-component acrylics. The multicolour possibility of Jotamastic 90 also proves significant improvement of hiding power for strong coloured topcoats. Improved wetting and penetrating abilities also give better intercoat adhesion.

Investment in corrosion protection is about calculating the cost of the coating over the lifetime of a project. The right decisions at new building stage and the correct choice of surface preparation and coating system for maintenance and repair is the key to maximize protection and optimize the return on investment.

"The new Jotamastic 90 utilizes modern technology and materials providing excellent wetting properties, ensuring even better surface penetration and adhesion to the substrate and resulting in a durable solution," said Lasse Isaksen, Product Manager Anticorrosives at Jotun Coatings. According to Isaksen, different coatings have different lifetimes. "The Jotamastic range offers great potential for savings through lower surface preparation costs, and is one of the marketâ&#x20AC;&#x2122;s most durable solutions compared with other surface tolerant epoxies," said Isaksen.

Oil Review Middle East Issue Three 2012 67

S14 ORME 3 2012 Tech Focus 1_Layout 1 05/04/2012 15:44 Page 68

Technical Focus

The development of a new class of environmentally acceptable corrosion inhibitors for oil and gas fields is now a reality.

Effective corrosion inhibitors

‘Green’ chemistry reduces the use of chemicals that are hazardous to the environment

‘go green’ T

HIS ARTICLE DESCRIBES the evaluation of a new class of chemical compounds for use as environmentally acceptable corrosion inhibitors. These water-soluble chemicals were developed as thermally stable inhibitors to mitigate CO2 induced corrosion in low and high shear environments. Furthermore, these products were effective for mitigating CO2 induced corrosion in various laboratory test environments.

68 Oil Review Middle East Issue Three 2012

The performance of these new products is compared to that of a highly effective traditional corrosion inhibitor. It was extremely challenging to develop new green chemistries that can compete effectively against non-green chemistries under a variety of conditions. These newly developed chemicals were highly effective in mitigating corrosion, while yielding more than 99 per cent protection at low dosage

rates (tested at 10 ppm). This article also describes secondary inhibitor properties such as oil water partitioning, and foaming tendency.

Governments and industry around the world are realizing that environmentally friendly chemicals are important to our general wellbeing. It is important to replace the chemicals toxic to humans and the environment with nontoxic or less toxic chemicals.

S14 ORME 3 2012 Tech Focus 1_Layout 1 05/04/2012 15:44 Page 69

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S14 ORME 3 2012 Tech Focus 1_Layout 1 05/04/2012 15:44 Page 70

Corrosion is a huge problem in the regional oil and gas sector

Green chemistry, or environmentally friendly chemistry, prevents or reduces the use or production of chemicals that are hazardous to the environment and human beings. Green chemists search for ways and means to reduce or eliminate acid gas emission, production of waste at the end of a chemical process, use of toxic solvents, and creation of harmful by-products.

Many oil and gas producing formations yield hydrocarbons, brines, carbon dioxide, and/or hydrogen sulfide. All of these are very corrosive to metal tubing, pumps, casings, and other production equipment. Corrosion is high in wells producing brine since they contain high levels of dissolved acidic gases (such as carbon dioxide or hydrogen sulfide), inorganic salts, or low molecular weight organic acids such as acetic, formic, or propionic acid. These chemical components increase the corrosivity of the medium when dissolved in water at elevated temperatures.

Corrosion prevention of metallic surfaces is an important industrial task. When metallic surfaces oxidize, metallic ions either convert to soluble salts, insoluble metallic oxides, hydroxides, carbonates, or sulfides. The oxidation of the metallic surface causes its deterioration and results in scale buildup. The traditional and most common way to reduce corrosion is to add a corrosion inhibitor to the corrosive system. Corrosion inhibitors are watersoluble and/or oil soluble chemical compounds that inhibit corrosion by changing the surface conditions of the metal when added in small quantities to an aggressive medium.

The traditional organic inhibitors for corrosion are typically derived from aliphatic and aromatic amines, polyamines, imidazolines, and imidazoline salts, among others. Inorganic corrosion inhibitors include chromates, zinc phosphates, and silicates. Although these commercially available corrosion inhibitors eliminate or reduce corrosion on metallic surfaces, they are harmful to the environment.

Operating companies, governments, and the public have become increasingly concerned about the toxicity and environmental impact of oil field chemicals; especially in offshore applications. In offshore operations such as the

70 Oil Review Middle East Issue Three 2012

North Sea, environmentally sound chemicals are very important.

While countries like those in the North Sea have regulatory agencies that demand environmental testing and registration for all chemicals, other regions also see the benefit of using more environmentally friendly corrosion inhibitors.

Numerous tests are performed on the raw materials utilized in corrosion inhibitor formulations to evaluate toxicity, bioaccumulation, and biodegradability. Corrosion inhibitors should be non-toxic to aquatic life, biodegradable, and reasonably water-soluble in order to protect the marine environment.

Furthermore, the flash point of the solvent and the solvent-evaporating factor of the chemicals should be considered in designing these inhibitors as lower flash point products can be fire hazards.

As a leading supplier of corrosion inhibitors, Clariantâ&#x20AC;&#x2122;s focus has always been to design corrosion inhibitors with low impact to the environment. This is a difficult task because traditional non-green chemistries are generally more effective and less expensive.

Development of environmentally sound products can compromise desired performance. Most nitrogen and phosphorous based inhibitors currently used in our industry carry inherently toxic properties. Therefore, it is indeed a challenge to develop chemistries that are benign to the environment and relatively cost effective. The final goal of Clariant is to replace all current corrosion products with cost comparable chemistries that are both green and as effective as traditional non-green chemistries.

Two approaches to this dilemma are described below. The first approach was to develop synergistic effects by combining known classes of green bases. A series of products were blended methodically. The second approach was to design new molecules that are potential candidates as green corrosion bases.

This has been achieved through collaboration with an industrial partner. The first approach is to meet short term goals and the second approach is to meet long term goals. The

ultimate focus is to develop corrosion inhibitors that are more cost-effective than a particular product which has been very successfully used in the North Sea region for more than a decade.

This chemical is denoted as Chemical C. This article describes the development of environmentally friendly corrosion inhibitors by both approaches.

Clariant has been at the forefront of green chemical development and has a vast array of green and low-toxicity base chemicals. After extensive screening, one formulation (Chemical B) out-performed the traditional product (Chemical C). Screening of formulations using newly developed compounds yielded a series of new chemical formulations. Out of this series, one product (Chemical A) was selected based on its efficacy, water solubility and stability.

These new products are not expected to create foams or emulsions.

More than one hundred inhibitor formulations were screened as corrosion inhibitors at Clariantâ&#x20AC;&#x2122;s Aberdeen (Scotland) and Houston (USA) laboratories. They were evaluated under several different laboratory conditions. Two of the corrosion inhibitors were new green blends (Chemical A and Chemical B), and one was a pre-existing chemical (Chemical C) that has been widely used in the North Sea area for more than a decade. Chemical A is a chemical whose raw materials were blended utilizing the newly developed chemical compounds. Chemical B is comprised solely from existing and approved green intermediates already in use.

Chemical C was primarily used in the testing to set a precedent of performance by a nongreen corrosion inhibitor that we were striving to meet or exceed with a green corrosion inhibitor.

The Corrosion Inhibitor packages were evaluated by several types of electrochemical laboratory tests.

In the first test, we employed the aqueous rotating cylinder electrode method (RCE). The two phase testing solution used was 90 percent synthetic brine and 10 percent synthetic oil. The synthetic brine was comprised of 3.5 per cent sea salt and

S14 ORME 3 2012 Tech Focus 1_Layout 1 05/04/2012 15:44 Page 71

repeated several times and the performance results obtained were very similar.

The second method we employed was RCE bubble tests. The RCE bubble test was conducted with 3.5 per cent sea salt, 150°F and with 10 ppm corrosion inhibitor chemical.

The test was conducted to study the partitioning behavior of the chemicals. The RCE test equipment was set up exactly as described above but the tests were conducted with stationary electrodes. The only agitation was by 100 per cent CO2 gas bubbling through the total fluid in the test vessel. The brine to oil ratio was 9:1 and 10 ppm of each chemical was added to the oil phase of the solution; allowing the chemical partition to brine without much agitation. The corrosion rate of this static test exhibited the same trend as shown in RCE aqueous tests. The Chemical A with newly synthesized compounds was slightly better in corrosion mitigation than Chemical B which is made of existing green intermediates. Both outperformed the bench-mark traditional corrosion inhibitor C. Chemicals A and B were tested for foaming tendency in several oil field brines. The products are not expected to foam. The laboratory evaluation indicated that these products do not

create emulsions. Both products are soluble in 3.5 per cent sea salt brine.

Clariant carries several effective green corrosion inhibitors in the corrosion product line. The goal of this project was to develop several chemicals that are environmentally benign while being cost and performance similar to or better than an excellent benchmark chemical from traditional chemistry. The test indicates that both green products performed better than the bench-mark chemical (Chemical C). The effective concentrations of all three products are very close to each other and Chemical A and Chemical B are expected to be very comparable in the price range to the bench-mark chemical. With more than 99 per cent protection at 10 ppm of each chemical, these chemicals can replace traditional chemistries in the North Sea as well as around the world where environmental restrictions are currently not enforced. ■

Authors: Nihal Obeyesekere Ph.D., Thenuka Ariyaratna, Clariant Oil Services, 2645 Technology Forest Blvd., The Woodlands, TX 77381, USA and Alistair Kirkpatrick, Clariant Oil Services, Howe Moss Place, Kirkhill Industrial Estate, Dyce, Aberdeen AB 210GS, United Kingdom

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Technical Focus

deionized water. The synthetic oil used was LVT 200. All tests were run with de-aerated brine and oil (90:10) that were continuously sparged with 100 per cent CO2 gas. A constant temperature of 150°F was maintained over the duration of the test using a hot plate with an integrated temperature probe. The RCE test method was run at 2000 RPM. All tests were allowed a minimum of one hour to collect a baseline corrosion rate prior to the addition of the inhibitors. All corrosion inhibitors were added at 10 ppm based on total solution volume.

Under both high shear and high CO2 saturation, Chemical A proved to be an excellent corrosion inhibitor across a wide spectrum of conditions. Chemical A showed a sharp drop in corrosion rate as soon as it was added to the system and continued to lower the corrosion rate as time progressed. Chemical B showed the most aggressive drop in corrosion rate, surpassing even Chemical A initially, but eventually was outperformed by Chemical A after approximately 14 hours. Chemical C was outperformed by both Chemical A and Chemical B The tests were conducted in relatively high shear, and the results indicated both products A and B out-performed the traditional Chemical C at a very low concentration. This test was

S15 ORME 3 2012 Tech Focus 2_Layout 1 05/04/2012 15:37 Page 72

Technical Focus

The Middle East continues to provide a steady and reliable source of work for drillers, despite global oil demand fears and rising tensions in the Gulf.

Roughnecks and

rigs A

S THE WORLD’S greatest oil and gas producing region, the Middle East is a natural magnet for drillers and a key fixture in the global rigs market.

And activity appears little changed in the region from a year ago, despite the uncertain energy demand backdrop in Europe and elsewhere that is now troubling key oil and gas producers such as Saudi Arabia, Kuwait and Iran.

In a January update, drilling rig analysts IHS Petrodata reported that there were 121 rigs in the total drilling fleet across the Middle East region, just two up from the 119 recorded in the same month in 2011.

Significantly, however, rig utilisation rates had stepped up a notch during the same period.

IHS reported that 99 rigs of the total fleet were under contract in January, compared to just 90 a year earlier. It represents a utilisation jump from 75.6 per cent to 81.8 per cent, which, according to the figures, is slightly above the worldwide average.

It is welcome news for the doom merchants concerned that the economic headwinds in Europe and beyond would drive down demand and activity.

The tanker segment remains prosperous too, although this is in part a result of tensions in the Gulf, according to shipping experts Clarksons.

“Following the holidays, moderate activity in the Middle East Gulf and fears about Iranian manoeuvres in the Straits of Hormuz helped keep

72 Oil Review Middle East Issue Three 2012

rates from collapsing,” it noted in a January bulletin.

The latter statement suggests that the market could be more fragile without the uncertainty now emanating from Iran and the spectre of a Hormuz closure, even if short-lived.

Lamprell limbers up For now, things are looking up for the region’s active rig suppliers and drilling firms.

UAE-based rig maker Lamprell netted in excess of US$1 billion worth of new orders during 2011, closing the year with a deal to supply a selfelevating mobile offshore platform to PEMSA (Compañía Perforadora Mexico S.A.P.I. DE C.V.), a subsidiary of Grupo Mexico.

It maintains a healthy order book too, worth around US$1 billion, stretching into 2014, plus a bid pipeline worth US$4.2 billion as at the end of last October.

The company is now targeting deeper penetration in other regional markets such as Saudi Arabia, Kuwait and Iraq although there remains good future potential in its core Abu Dhabi stronghold with projects such as Upper Zakum, Satah al-Razboot and Umm Lulu.

Last year was one of expansion generally for Lamprell, which completed the acquisition of Maritime Industrial Services (MIS) in September, a move that will grant it greater access to the Saudi

market through the successful MIS Arabia business.

Integration of the rival rig company into the enlarged Lamprell group is expected to yield cost synergies of around US$11mn per year.

The London-listed company now employs over 11,000 people across six sites, with its primary facilities in Hamriyah, Sharjah, and Jebel Ali, plus Saudi Arabia.

Management reported at the close of 2011 that the outlook for the year ahead remained positive.

Indeed, the company was highlighted in an endof-year investment report as one of the 2012 shares to watch by the UK’s Times newspaper, as it makes the transition from mid-size regional player to larger regional player with a broad Middle East footprint.

Inside the Gulf region’s biggest oil producers, there remains an ongoing demand for rigs and all associated services, which means steady work for state-owned suppliers.

Abu Dhabi’s National Drilling Company (NDC) part of the state-owned Abu Dhabi National Oil Company (ADNOC) - continues to grow and modernise its fleet.

Already one of the region’s largest drillers, the company last year awarded a US$333mn contract to Lamprell for the construction of two high powered LeTourneau Super 116E Class jack-up rigs.

Jack-up oil rigs are mobile platforms positioned to drill into the sea floor, typically used in shallow waters.

S15 ORME 3 2012 Tech Focus 2_Layout 1 05/04/2012 15:37 Page 73

Technical Focus

S15 ORME 3 2012 Tech Focus 2_Layout 1 05/04/2012 15:37 Page 74

“Substantial increases in production will see strong growth of drilling activity in China, India and Iraq ... while investment in enhanced oil recovery techniques in Saudi Arabia and Kuwait are expected to boost productivity in some of the world’s largest maturing fields,” the report states.

To facilitate greater Iraq business onshore, insurers Marsh and Anglo Arab Insurance Brokers (AAIB) recently launched a new land rig facility providing easy cover for rig loss or damage in this high potential but risky market.

The facility can be tailored to meet the specifications of one-shot well exploratory drillers, through to larger contractors conducting significant drilling operations across Iraq, reckons Simon Boxall of Marsh’s energy practice.

“This facility enables all contractors, from small independents through to global firms, to pioneer the development of Iraq’s oil economy,” he said.

Drilling services

Rig activity in the region has seen little change and will remain a vital source of work

The new acquisitions - triangular hulls with three 310 ft legs, and capable of drilling in waters up to 200 ft deep - will provide a significant boost to NDC’s already busy fleet.

The year before, the company committed to doubling its then 28 onshore and offshore drilling platforms over the next few years.

Another NDC rig, al-Bzoom, which had been undergoing significant refurbishment works - again

by Lamprell, this time at its Sharjah yard - was also re-delivered in October 2011, further enhancing the fleet.

Likewise, Kuwait Drilling Company’s growing fleet has served Kuwait’s prized oil industry for more than four decades.

Over the last five years or so the company has effectively quadrupled its operations and it continues to expand rapidly.

And, like NDC, it also aims to establish itself as a regional contender.

The world’s biggest private drillers are also

74 Oil Review Middle East Issue Three 2012

enjoying the benefits of some stable work in the region.

Noble Corporation of the US has about a dozen offshore rigs dotted around the Gulf, operating principally in Saudi Arabia, Qatar and the UAE. The company successfully negotiated new deals on a number of rigs coming out of various shipyards towards the latter part of 2011, mainly with Saudi Aramco; some of these contracts now carry on through to 2014.

The most lucrative deal, for the Noble Scott Marks jack-up, on charter to Saudi Aramco until July 2014, is on a hire rate of US$237,000 a day.

In the Middle East, however, the opportunities are not just offshore, but onshore too.

According to a report, The World Land Drilling Rig Market Report 2011-2015, collated by energy consultants Douglas-Westwood, the region still offers high potential singling out markets such as Saudi Arabia to see an increase in the number of active rigs.

US drilling giant Halliburton has stepped up its involvement in Saudi Aramco’s huge Manifa project.

The project has been running with one rig, but it originally targeted 10 rigs for the offshore component, which Halliburton announced when it won the contract nearly four years ago.

It suggests more work to come in this primary oil and gas market.

The US contractor is also working on a five-year turnkey drilling contract in South Ghawar, with work in Uthmaniyah, Haradh, Hawiyah and Shedgum.

Located 200-km from Dhahran, the Ghawar field is the world's largest oilfield.

Other international drilling service companies have made great efforts in recent years to get closer to local markets.

In Saudi Arabia, this has meant foreign services firms linking up with local engineering specialists to gain the best chance of accessing future work.

One thing seems certain: the increasing complexity of upstream work suggests that there will long be a role for these companies in the region, despite the trend to bolster local skills and indigenous employment.

In the Saudi-Kuwait Divided Zone, for instance, Chevron is leading a steam-flood technology project to aid heavy oil recovery rates from complex reservoir systems.

Similarly, Abu Dhabi is working with the US’ Occidental Petroleum to tap its deep Shah sour gas deposits.

Oman too, while keen to foster its ‘Omanisation’ policy, faces equally tough challenges in the field, as it gets to grips with its tight gas potential, in partnership with the likes of BP and Occidental.

This means plenty of work to come for the leading drilling contractors that work hand in hand with the major international oil companies all over the world, and no more so than in the Gulf.

As long as their skills, technology and expertise are in demand, then the Middle East is likely to remain a vital source of work for the drillers, rig contractors, and services providers of this world. ■

S15 ORME 3 2012 Tech Focus 2_Layout 1 05/04/2012 15:37 Page 75

Technical Focus

S15 ORME 3 2012 Tech Focus 2_Layout 1 05/04/2012 15:37 Page 76

Mansour Belhadj, Regional Sales Director, Honeywell Process Solutions, Middle East, spoke to Oil Review about the growing emphasis on wireless technology and the benefits it can bring to the hydrocarbon industry

Honeywell outlines plans for

closer integration H

ONEYWELL PROCESS SOLUTIONS has been involved in all aspects of oil and gas, from upstream (offshore and onshore) to downstream facilities (gas processing, refining and petrochemical plants), providing an integrated solution that aims to improve safety, reliability, efficiency and sustainability to operating plants.

“Our vision is to yield sustainable benefits and value to end users for the very long term,” said Mansour Belhadj, Regional Sales Director, Honeywell Process Solutions, Middle East.

Belhadj explained how Honeywell is focussing efforts on presenting itself as ‘One Honeywell’ as there are many divisions within the organisation offering a diverse portfolio of products and solutions to the process industry. The real focus is to push towards integration so that the company can provide high added value solutions to customers.

An example of this level of integration, according to Belhadj, is Honeywell’s ability to optimise an operating plant, from field instruments to business applications, in a seamless fashion. He also highlighted Honeywell’s focus on the continuous development of innovative new products. An example of this is the company’s latest portable gas detector, which is used to ensure field operators’ onsite safety and positioning and is fully integrated with the Experion Control system.

“Honeywell portable gas detectors analyse atmosphere gas continuously to inform about safe environments for operators,” said Belhadj. “The communication is established wirelessly with the Experion Control System which displays continuous gas analysis results and provides the operator location within the plant in a dynamic fashion. This innovative portable device augments tremendously operator’s safety.”

“Wireless technology is becoming increasingly important within the oil and gas industry,” said Belhadj. “Today wireless based products are taking a large place in our portfolio. Wireless Technology is proven to reduce project cost tremendously and helps enable multiple value applications to improve safety, reliability and efficiency. Honeywell wireless technology is used in several areas today, within operating plants such as process instrumentation, asset management, centralised monitoring of mobile operators, safety compliance, etc.”

In addition, wireless technology can not only used for information, but can also be used for control.

“Wireless is certainly the direction we are taking and there is a growing demand in the region,” said Belhadj “Wireless is one area of focus for growth and we are continuously looking at improving our existing technology with wireless products to meet customer’s objectives and key performance indicators.”

Honeywell R&D is strongly guided towards wireless technology.

“We have new products launched on a yearly basis,“ said Belhadj. ”We operate in a very competitive environment and are always looking at ways to address this through new technologies and innovation. R&D is a major focus of our business and although the world is going through economic difficulties, Honeywell has not stopped investing in new products through its powerful R&D arm. We believe it will help the company to be better positioned as a technology provider now and in the future.”

Belhadj talked about Honeywell’s main growth markets and the company’s aim to “localise resources on the ground”. A real driving force for Honeywell is to increase its local skilled resources based in the region through its Middle East training facilities and Centres of Excellence.

“Our primary objective is to train local graduates to build generations of experienced engineers and managers for the future,“ said Belhadj. ”Honeywell has established the JETPro (Junior Engineers Training Programme) in which fresh

76 Oil Review Middle East Issue Three 2012

graduates from top universities are hired and trained thoroughly by Honeywell to become skilled engineers in our business.”

Belhadj mentioned the Qatari market, in which Honeywell has a large base.

“Despite a slowdown in the pace of project investments compared to previous years, the Qatari market is still forecasting several exciting projects and we are fully prepared to go after this business,“ said Belhadj. ”Honeywell has invested in a Centre of Excellence for Advanced Solutions based in Doha to serve the Qatari market and other GCC countries. Our objective is to remain closer to Honeywell end users and act/support locally in order to grow customer satisfaction and our business. Qatar is viewed as a key area of growth for the coming years.”

Honeywell is also focusing heavily on the Saudi Arabian market and striving to increase its resources in the Kingdom.

“We have invested in world class facilities, offices and project areas at the Daharan Techno Valey (DTV). This shows the importance of the Saudi market for Honeywell,“ said Belhadj. “The DTV offices will host several Honeywell divisions, among them Process Solutions (HPS), Building Solutions (HBS), Life and Safety (HLS) and the Honeywell process licensing business (UOP). So it will be a truly a ‘One Honeywell’ facility. This is sending a very strong message of long term commitment to the Saudi marketplace.

“Honeywell has first class training facilities located at DTV dedicated for Saudi Arabian customers. There is also a strong focus in partnering with key universities such as King Fahd University of Petroleum and Mining (KFUPM) to train students on Honeywell Technologies and develop strong future generations of skilled engineers. In addition, Honeywell has implemented the JetPro programme, targeting new graduates in engineering disciplines.”

Iraq is also a major focus for Honeywell, where the company predicts strong growth in the coming years.

“We have opened offices in Baghdad and Basrah with resources locally based and operating in Iraq,” said Belhadj “Our goal is to keep focusing on this market and be close to customers to answer their needs rapidly. Raising [the level of] skills in Iraq is a key challenge. Our objective as an international company is to bring our knowledge and technology to the local market to help improving safety, reliability and efficiency for existing and future operating facilities.”

This translates into heavy investment in facilities and resources. To address the challenge to build knowledge and skills in Iraq, Honeywell’s Basra office will host a full training centre, displaying most of Honeywell’s automation solutions and dedicated to training local customers.

Honeywell is also strongly established in the UAE and, for many years, Honeywell Abu Dhabi has acted as an engineering hub for the Middle East region.

“Today, we still have the largest engineering centre in Abu Dhabi; however we have developed projects and engineering capabilities in all GCC countries to implement projects and support customers locally,” said Belhadj.

The company’s level of investment in the UAE is increasing year after year and Honeywell is about to open a large, world class Customer Engineering Centre in Abu Dhabi. This is the third Honeywell project facility in Abu Dhabi.

“We have invested a lot to meet growing customers demand and are hiring aggressively to supply skilled resources to the large volume of projects we are dealing with,” said Belhadj.

He ended talking about the increasing opportunities in the downstream sector.

“We see growth in the downstream sector with new refineries coming up around the region,” said Belhadj. “There are a number of new mega petrochemical plants announced for Saudi Arabia and Qatar which bring more excitement and energy to our business.” n

S16 ORME 3 2012 Tech Focus 3_Layout 1 10/04/2012 11:29 Page 77

Technical Focus

S16 ORME 3 2012 Tech Focus 3_Layout 1 05/04/2012 15:32 Page 78

Gianni Minetti, President and CEO of Paradox Engineering SA, examines wireless sensor networks and their applications for remote and condition monitoring of oil and gas sites.

The benefits of wireless

sensor networks W

HILE A 42 per cent increase in oil reserves is projected by 2030, the natural gas sector is also enjoying rapid growth, with the International Energy Agency (IEA) forecasting that natural gas usage could double over the next 25 years and account for a quarter of the world’s energy demand. However, increasing volumes do not necessarily mean increasing profits: today’s oil and gas companies need to improve control over site performance and maximise production efficiency if they want to achieve their financial goals. The evolution of exploration and production technologies is fundamental to increase production while cutting costs, but relevant results can be obtained by revising data management processes to ensure that decisions are made as quickly as possible and are, above all, based on consistent and reliable information.

Real-time production monitoring can be accomplished successfully through a comprehensive and secure approach to data collection, transport and analysis. Companies can unlock the value of information coming from the production workflow only if they have a solid infrastructure to collect data from wells, refineries, production plants, pipelines and facilities. They then need to streamline this huge amount of information into their ICT systems, where it will be stored and processed in order to extract key and relevant information to increase efficiency and prevent production losses.

The challenge of condition monitoring is even more complex if we consider that oil exploration interests tend to move to harsh areas, such as offshore or in the Arctic, where the highest volumes are expected. As for natural gas, conventional sources will continue to represent the greater part of global supplies, but unconventional sources (shale gas or coalbed methane, for instance) will become increasingly important, therefore reinforcing the need to strictly monitor production.

So what is the best way to collect and transport data coming from remote and even hazardous environments? In many cases, wired infrastructures are already in place, and companies are unlikely to upgrade the network or add new data points due to the additional cost. In a typical oil or gas facility, thousands of sensors and data points are needed to ensure proper asset monitoring, with hundreds of thousands of metres of cables used to connect these devices. If a brand new offshore platform has approximately 800-km of wiring, for example, with the cable costing from US$120 to US$6,000 per

78 Oil Review Middle East Issue Three 2012

metre, it is easy to understand why oil and gas companies are eager to protect their past investments and may not be open to possible alternatives.

Maintaining wired process and sensor networks may prevent companies from successfully dealing with market demands or regulatory changes, however. Such changes may require increased performance and efficiency by increasing data collection frequency or installing additional data points (ie to monitor emissions or new security parameters). Traditional infrastructures are often complex to expand or integrate, especially in hardto-reach locations or harsh environments where wired connectivity and wired networks can prove difficult to install, unreliable, too expensive or simply unviable.

Wireless sensor networks can offer oil and gas companies immediate and measurable benefits, including improved performance, greater flexibility and reduced costs for installation and ongoing maintenance. Wireless data acquisition and transmission allow companies to have deeper, more granular and accurate information from production assets, therefore enabling effective plant monitoring and supporting real-time decisions thanks to the ability to feed all data directly into corporate ICT systems.

As for the initial investment, a wireless technology project can cost up to 50-70 per cent less than the wired option – considering hardware/material costs, engineering, installation, and global administration and management. There are several additional benefits as well, including: increased operational reliability and system uptime, increased operator and engineer productivity, improved asset utilisation and personnel safety and many others.

Of the several options available on the market, the best approach seems to be to go for open standard, scalable and vendor-independent wireless networks, so as to offer the best return on investment. No changes to existing data points need to be made, for instance, allowing wireless devices to be implemented directly over the current sensor infrastructure without requiring any infrastructure upgrade. This allows one network to be built and ‘plug and play’ applications added when needed at a fraction of the initial cost.

RF penetration, noise immunity, dynamic adaptation of network topology should be evaluated, since both parameters are particularly critical for reliable data transmission in oil and gas plants.

Industrial wireless sensor network solutions generally use RF transmission on 2.4 GHz or above, which often proves to be inefficient in congested environments

Wireless sensor networks can offer oil and gas companies immediate and measurable benefits

Of the several options available on the market, the best approach seems to be to go for open standard, scalable and vendorindependent wireless networks and features a low penetration factor. Solutions based on IETF open standards – such as 6lowPAN – on subGHz ISM band with full mesh topologies should be preferred, as they grant higher penetration, noise immunity and dynamic adaptability to changes in the surrounding environment.

Other benefits of wireless sensor network solutions are more difficult to quantify, but are still worth listing. As the system grows and more points are monitored and additional applications added, more data will be added to the company knowledge systems; if the choice has been for a bidirectional, M2M wireless network, instrument calibration and equipment diagnosis can be performed remotely and more often – thus reducing equipment failures or forced shutdowns.

Another benefit is that most valid wireless sensor network solutions require no software to install, no heavy server side operations and very little maintenance. In brief, they provide almost unmanned deployment coupled with a selforganising, self-healing, adaptive and fault tolerant network. This is important for all industries, but particularly relevant for oil and gas companies.

Considering the harsh locations where plants are

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Technical Focus

S16 ORME 3 2012 Tech Focus 3_Layout 1 10/04/2012 11:51 Page 80

WSN Outdoor Gateway

usually installed, shrinking workforce and budget constraints, no complexity in implementation, roll out and maintenance processes can be afforded.

Authentication, authorisation and strong encryption – ie, security - complete the set of features together with an extended range of temperature and hazard/explosion safe hardware

and web-based management applications to further streamline configuration and management. Ultra low power technology coupled with long life battery operation (more than eight years) help further to streamline labour and personnel intervention and overall efficiency.

Selecting a wireless sensor network that is ready to scale up from narrow band to broadband to link data to the HQ is an attractive solution, offering connectivity in typical oil and gas plant locations, where landlines are unreliable, difficult to access or nonexistent. Working with a satellite network provider, or virtual network operator, is an interesting option to consider when developing tailored solutions and, if necessary, hybrid infrastructures for business continuity applications and redundant communications.

Due to the complexity of real-time production and condition monitoring within the oil and gas industry, wireless sensor network solutions can be particularly successful in providing an effective approach to data collection and transportation,

increasing overall plant efficiency. Thanks to innovative wireless sensor network technologies, oil and gas companies have the opportunity to utilise the value of all of the information coming from their assets and production workflow. Lessons from this market are useful and can be applied to all industrial organisations that have dispersed plants and facilities that need to be monitored, however. n

Gianni Minetti is President and CEO of Paradox Engineering SA, and founded the company in 2005.

Paradox Engineering SA is a Swiss company whose portfolio includes industrial wireless sensor networks, smart metering solutions, global virtual networks for companies where smart grid, energy management, condition and remote monitoring, industrial process monitoring, engineering and telemetry projects require future proof and cost effective solutions to unlock the value of data.

Paradox Engineering SA acts as a global provider of turnkey solutions and technologies through a consolidated network of strategic partners.

Hydraulic fracturing - ‘proven technology’ supported by ExxonMobil and GE COLORADO SCHOOL OF Mines, Penn State University and the University of Texas at Austin announced a new training initiative to support the rapidly growing shale natural gas and oil development sector. The training programs created under the initiative will be led by the faculty at each academic institution and are designed to ensure that regulators and policymakers have access to the latest technology and operational expertise to assist in their important oversight of shale development.

ExxonMobil and GE, two of America’s leading energy corporations, today announced they would each contribute US$1mn to this new educational initiative.

“Regulators have said that the need for increased training is one of their highest priorities due to the rapid expansion of shale resource development and the equally active evolution of technologies and best practices in the field,” said Gary Pope, director of The Center for Petroleum and Geosystems Engineering (CPGE) at The University of Texas at Austin.

Rex Tillerson To meet this demand, CPGE, which provides engineering leadership and technology innovation related to energy and the environment with special emphasis on the production of hydrocarbons from both conventional and unconventional sources, added an Education, Training and Outreach Program, directed by Dr. Hilary Clement Olson.

“This funding provides us with the resources to broaden our partnerships and our scope to create a new training program for regulators in the oil and gas industry that is collaborative and interdisciplinary,” said Olson.

Thomas Murphy, co-director of the Penn State Marcellus Center for Outreach and Research, said, “The Shale Gas Regulators Training program affords the university a unique opportunity to further develop shale gas best management practices and to offer new regulators the chance to learn the latest science-based concepts

80 Oil Review Middle East Issue Three 2012

related to geology, petroleum technology and environmental quality. Penn State looks forward to providing development training that will help ensure a strong, yet consistent, regulator process across the Appalachian Basin.”

Colorado School of Mines President M.W. Scoggins said, “Colorado School of Mines’ focused mission to educate the next generation of engineers and applied scientists fosters a natural partnership in this consortium. Our specialized curriculum and research program centered on responsible resource development is helping to enhance global understanding of our most pressing earth, energy and environmental challenges.”

Added Colorado School of Mines’ Dr. Azra N. Tutuncu, who is director of the school’s Unconventional Natural Gas and Oil Institute (UNGI) and Harry D. Campbell Chair in Petroleum Engineering, “The Unconventional Natural Gas and Oil Institute at Colorado School of Mines provides training for developing unconventional resources in an environmentally sound, safe and economically viable manner - the oil and gas industry as well as state and federal regulators and policymakers benefit from this expertise.”

The series of courses, which will primarily focus on the development of shale resources, will cover: 6 Petroleum geology, both conventional and non-conventional; 6 Petroleum technology, including principles of drilling operations and well design, as well as facility design and operation; 6 Environmental management technologies and practices, including water treatment and management, waste treatment and management, air emission control technologies, spill prevention and planning and response; and 6 Federal and state oil and gas regulatory requirements, including permitting and reporting, plus compliance assessment.

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The increasing production of shale resources means hydraulic fracturing and other technologies are in great demand

Technical Focus

GE and ExxonMobil believe that natural gas plays a critical role in America’s energy future. When used for power generation, natural gas emits up to 60 per cent less CO2 than coal. The integration of two proven technologies - horizontal drilling and hydraulic fracturing - has opened up more than 100 years supply of natural gas for US homes and business, creating an unprecedented pathway to enhanced energy security for the country. Natural gas also enables more renewable energy to join the power grid as next generation gas turbines help ensure grid stability by quickly ramping up and down to generate electricity when wind or solar power is intermittent.

“America’s shale energy resources are creating jobs and economic growth in regions across the country, and Americans rightly want to know that these resources are being produced safely and responsibly,” ExxonMobil CEO Rex Tillerson said.

“ExxonMobil is pleased to provide the resources to assist the schools in equipping regulators with the latest technical and operational knowledge being applied in this growing sector.”

GE CEO Jeff Immelt said, “Natural gas is dramatically changing the way we power America, and GE is committed to its responsible development. We believe advanced technology, an expert workforce and smart regulation are the keys to America leading the world in shale gas development. As a technology leader in the energy sector, GE recognizes the importance of minimising a site’s environmental footprint while simultaneously increasing operational efficiency.”

GE and ExxonMobil note that while hydraulic fracturing, horizontal

drilling and other technologies used to produce shale resources are not new, they are being used today on a larger scale than ever before.

Therefore, it is critical that regulators and policymakers have access to a sound scientific understanding of shale energy development and are fully aware of the technologies required to produce these resources safely and efficiently, while protecting the environment. That is why the two companies have offered their support for the professional development programs developed by these universities.

GE produces nearly 40 technologies for the shale resource sector in areas such as mobile and fixed water filtration, flare gas capture and reuse, cleaner on-site power generation and demand-side solutions that create liquefied natural gas or compressed natural gas for applications such as in-truck fleets.

“WellWhiz, (that models the fracture geometry explicitly), to design your well completions for optimal production performance.”

“Field-experienced specialists for all your stimulation operations worldwide.”

Fracture Technologies Consultants Web: Email: Phone:

www.fracturetechnologies.com info@fracturetechnologies.com +447770524740

Fracture Technologies WellWhiz Web: Email sales and info: Phone sales and info:

www.wellwhiz.com info@wellwhiz.com +447770524740

Oil Review Middle East Issue Three 2012 81

Novel traceable proppant enables propped frac height measurement while reducing the environmental impact. By Pedro Saldungaray, SPE, Terry Palisch, Robert Duenckel, SPE, CARBO Ceramics Inc.*

Propped hydraulic fracturing reduces

environmental risks F

RACTURE HEIGHT IS used by fracturing 10000 HTNCC IDC 30/60 IDC 30/60 97 94 In Size (-30 / +60) (%) engineers to calibrate propagation models.

HTNCC IDC 30/60 MPD, microns 493 490 An accurate height measurement reduces IDC 30/60 Crush (10k), % 1.2 1.1 ftASG, g/cc 3.28 3.31 d the uncertainty of fracture pressure m BD, g/cc 1.88 1.86 ,y ti matching, better determining frac length and width, Acid Solubility, % 3.0 3.4 v 1000 ti Shape, R/S 0.90/0.90 0.89/0.88 c stress profile across the target zone and its boundaries u Turbidity, FTU 97 81 d n and fracture containment. This is particularly important Chemistry o C Al O 72.4 73.9 when there is concern with vertical penetration into an SiO 15.4 13.9 TiO 3.0 2.9 unwanted zone, or determining adequate zonal Fe O 8.5 9.2 100 coverage and reserve reserves. In most cases, fracture Other 0.1 0.5 0 2000 4000 6000 8000 10000 12000 14000 Tracer 0.4 Stress, psi height is measured using radioactive tracers which are blended into the proppant at the wellsite. Clearly these Figure 1 – The addition of trace amounts of the HTNCC does not impact the physical performance of the proppant, nor does it affect the MSDS of the base proppant [Courtesy CARBO]. can present both a safety and environmental hazard and in some regions of the world their use is prohibited.

The use of propped hydraulic fracturing has extended from early application This paper presents innovative, environmentally responsible proppant in low permeability formations to all types of reservoirs, though the motivations detection technology and associated logging techniques for propped height may vary, most formations will benefit from hydraulic fracturing. Its scope today measurement and/or proppant placement. Its non-radioactive nature eliminates goes from fracturing extremely low permeability in unconventional reservoirs for the problems inherent in other tracing methods and, having no half-life commercial viability, to low permeability wells for reserve acceleration, to limitation, is permanently detectable. It provides for conducting multiple postfracturing high permeability unconsolidated formations for skin by-pass and frac logging at any time after fracturing, for initial assessment or to identify sand control. These operations can be conducted in horizontal, deviated, intervals for re-stimulation later in the well life. The tracing capability doesn’t vertical, open-hole or cased wells. The description below focuses on interfere with the proppants’ strength or conductivity, assuring adequate applications in cased boreholes in vertical wells, however analogous concepts performance. are applicable to all frac situations.

The theory and physical principles of the technology are discussed in detail Engineers design fracs, perforation placement and frac staging aimed at and supported by case histories of its application in various environments treating the whole targeted interval, but there may be zones within the desired around the world. fracture interval which are ineffectively fractured, due to anomalies within the 2

3 2 2

2

Measurement Type

Far Field

3

Features

Height

Length

Azimuth

Environment

Measurement Simplicity

Logging Speed

Forma on & Comple on Fluid Interference

Mul ple Tracer

Measurement ming

Cost

Microseismic

Hydraulic Medium

Medium

High

Physical Method

Complex

N/A

N/A

N/A

While fracturing

High

Tiltmeters

Hydraulic Medium

Medium

High

Physical Method

Complex

N/A

N/A

N/A

While fracturing

High

HTNCC

Propped High

Modeled

NO

Inert

Neutron

Standard

NO

Possible

Any me, Mul ple

Compe ve

RA Tracers

Propped High

Modeled

NO

Radioac ve

Spectral GR

Standard

NO

YES

Days to Weeks

Compe ve

RCTP

Propped High

Modeled

NO

Resin

Neutron + Specral GR

Low

Possible

Possible

Life of Resin

Extra resin coa ng cost

Acous c

Propped High

Modeled

NO

Medium

Std.

N/A

N/A

Any me

Medium

Temp Log

Hydraulic Low

Modeled

NO

Medium

Std.

N/A

N/A

Minutes to Hours

Low

Technique

Near Wellbore

Technical Focus

S16 ORME 3 2012 Tech Focus 3_Layout 1 05/04/2012 15:32 Page 82

Table 1 – Comparison of the various fracture geometry measurement techniques

82 Oil Review Middle East Issue Three 2012

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S16 ORME 3 2012 Tech Focus 3_Layout 1 05/04/2012 15:32 Page 84

Harsh Condi ons

Method Post frac log

Technical Focus

Region Method 1 Pre-Post CNT Texas

YES

China

YES

South America

YES

Rockies

YES

Africa

YES

Method 2 Pre-Post PNC

Changing Wellbore Environment

Method 3 Post CNL Only

OH CNL as Prefrac log

A er producing well

While Produc ng Well

YES

YES

YES

YES

Altered Forma on Fluid Satura on YES

YES YES

YES

Double casing

Varying Brine switched Comple on to Gas in Brine Density Wellbore YES

YES

YES YES

YES

YES

YES

Table 2 – Worldwide HTNCC experience

formation or problems within the borehole. It is also desirable to know: 6 Do the fractures extend vertically across the interval?

6 Has the fracture extended vertically outside the target zone?

6 The fracture height.

In all of these situations, knowledge of the location of the fractured and unfractured zones is very useful for planning remedial operations in the subject well and/or utilizing the information for designing frac treatments on future wells.

Fracture height measurement The available technologies for fracture height measurement are: 6 Far-field measurements. The two most popular technologies are tiltmeters and microseismic. In the first, an array of surface or downhole tilt meters is used to determine fracture propagation. These sensors can detect minute changes in the earth’s surface contours or deformation downhole induced by fracture creation. These displacements can be interpreted to locate fractured intervals, frac azimuth, length and height. In general, tiltmeter fracture mapping only provides overall fracture dimensions and azimuths but not accurate details of fracture growth.

Microseismic uses a downhole geophone array placed in a nearby offset well to record the microseisms resulting from the fracturing process. By mapping the location of the microseism it is possible to estimate height and length of the induced fracture. Like tiltmeters, microseismic is most suitable to determine frac azimuth and frac length and, to a lesser extent, height given its resolution.

These techniques measure only the propagation of the hydraulic fracture in

the formation and do not necessarily demonstrate that proppant was transported and placed there.

Near wellbore techniques. Most near wellbore technologies involve acoustic measurements, temperature logs or nuclear technologies: 6 One acoustic method uses differential cased-hole sonic anisotropy (DCHSA) measurements to determine fracture geometry. Variations in in-situ stress induced by the frac width are measured comparing pre and post-frac dipole shear sonic tools. Data inversion allows determining propped fracture height and width, as well as azimuth if crossed dipole is used.

6 Temperature logs rely on measuring the cooling effect produced by the frac fluid penetrating the reservoir where the frac has been created. These have long been used, however the surveys are sometimes difficult to interpret due to unusual temperature behavior adjacent to the treatment zone. Another drawback is that, similarly to far-field methods, temperature effect is related to fluid but not proppant placement.

6 Today, the most common nuclear methods use radioactive materials with half-lives of days to months mixed with frac fluid prior to pumping and a gamma ray detector, usually with spectroscopic capabilities, to log the desired fracture interval. These techniques have the ability to spectroscopically resolve signals from multiple tracers and distinguish tracer from formation gamma ray emitters or those from deposits on tubulars. However, this technique has several limitations: 6 Radioisotopes can have relatively short half-lives and their effectiveness diminishes from decay prior to use.

6 These isotopes are radioactive, so the logistical expense of RA monitoring of personnel is mandatory.

6 The possibility of radioactive contamination should there be an accident.

6 Radioactive material left downhole may interfere with post-frac nuclear measurements.

6 There are environmental, regulatory, and security issues since these gamma ray emitting materials create a radiation concern during all operational phases.

6 Since a tiny volume (often less than a gallon) of radioactive particles is blended into high fluid volumes, they may segregate and not truly reflect the fracture geometry.

In another technique, one or more stable isotopes which can be activated by a neutron source are incorporated into the proppant with a resin coating. After downhole placement of the Resin Coated Tagged Proppant (RCTP), a logging tool is run which activates them. The gamma rays from the resulting decay of these activated “tracer” nuclei are detected and analyzed to identify the proppant, and hence the frac zones. This technique also has several limitations: 6 The neutron source will activate both these tracers and numerous other nuclei present in the well, presenting interpretation problems.

6 Nuclei with longer half-lives take longer to activate, hence slow logging speeds may be required to generate enough signal.

6 The depth of investigation is relatively short since the source neutrons and secondary activation gamma rays traveling through the formation/borehole are exponentially attenuated, reducing the depth of investigation.

6 A background subtraction method is usually required, using off-peak subtraction in the observed spectra requiring high resolution detectors.

Traceable proppant This new nuclear technology addresses the difficulties described above. Low concentrations of a high thermal neutron capture compound (HTNCC) are added to proppant grains in the manufacturing process . The proppant is pumped

84 Oil Review Middle East Issue Three 2012

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Technical Focus

downhole and the HTNCC is detected using a Compensated Neutron Tool (CNT) or Pulsed Neutron Capture (PNC) tool which provide three different methods for detecting the proppant: 6 Compensated Neutron Logging Tools. A conventional CNT (preferably the same) with a continuous neutron source and one or more thermal neutron detectors is run before and after the frac job. The resulting count rates and near to far detector count rate ratios are recorded. A lower post frac count indicates proppant presence.

6 Pulsed Neutron Capture Logging Tools. Similarly the second method utilizes a run before and after the frac job. The decay curve count rate detected by gamma ray or thermal neutron sensors is recorded after fracturing the formation. The pre and post-frac PNC parameters are compared and the formation and borehole thermal neutron absorption cross sections are calculated from the PNC decay curves. These comparisons identify the presence of proppant.

In both the CNT and PNC methods above it is desirable to normalize the log responses utilizing intervals logged outside the zone where induced fracturing is possible. It may be possible to eliminate the pre-frac log entirely if a PNC or CNT log has previously been run in the well as described below: 6 Post-frac CNT log only. CNT logs are required only after the frac job, where the near to far detector (N/F) ratios and the individual detector count rates are utilized in the interpretation process. Despite CNT detector count rates and N/F ratios being sensitive to formation porosity and fluid saturation, the N/F ratio is virtually independent of HTNCC proppant presence. If wellbore conditions are uniform, logged intervals not containing HTNCC proppant can be used to develop a unique relationship between near and far detector count rate and N/F. A synthetic pre-frac log of CNT count rates can be generated using these relationships to serve as the baseline for post-frac CNT count comparisons.

These methods generally require the same conditions across the logged interval: a uniform borehole diameter, the same casing and good cement bond.

If a CBL is planned a CNT can be run too and/or an open hole CNT can be used in some situations as the pre-frac cased hole log for the first method above, but the open hole log must be normalized to match the response of the post-frac CNT in an interval without tagged proppant.

HTNCC proppant advantages The HTNCC is added to the ore used to manufacture ceramic proppant after the ore is ground and before forming the pellets to ensure uniform distribution without need of coating or additives to attach it to the proppant substrate. This enables detection of the propped height, which is the portion of the frac actually contributing to well productivity and determining reserve recovery, rather than the hydraulic height discussed above. The HTNCC is incorporated in small proportion , thus retaining proppant strength and conductivity which determine proppant and fracture performance (Figure1).

Being a non-radioactive material HTNCC is environmentally and operationally acceptable, has no limited half-life or suffers degradation, so is permanently detectable and overcomes RA tracer limitations. Logging during the life of the well allows identification of unpropped intervals years in the future.

The HTNCC proppant changes the response of a neutron log when present and is unaffected by formation type or chemistry. It is detected using standard neutron logging tools run at up to 1800ft/min and good acoustic coupling (cement bond) is not mandatory for Methods 1 and 2. The depth of investigation of HTNCC is typically the same as that of the CNT or PNC tools and similar to other near wellbore measurements.

A comparison of these fracture geometry measurement techniques is shown in Table 1. The green/yellow/red color-coding indicates high/medium/low measurement confidence and benefit (green) or drawback (red) of the technology.

6 Post-frac logging up to two months after the frac due to wellbore access

Field Examples There is ample field experience of HTNCC proppant for propped fracture measurement and detection in the United States, South America, Africa and Asia. Diverse challenges in applying the technology include post-frac logging timing and changes to the wellbore environment. Among the first category were:

problems.

6 Wells flowed after the frac and prior to the post-frac log, with consequent changes in formation fluid saturation complicating interpretation.

Variations in the wellbore environment included:

6 Changes in wellbore fluid density.

Oil Review Middle East Issue Three 2012 85

Technical Focus

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6 Changes from completion fluid (liquid) to gas.

6 Changes in liquid level between logging runs.

6 While not recommended, the post-frac CNT was run in a flowing well with variations in wellbore fluid density.

6 Double and/or different casings across the logged interval.

In all cases the interpretation methods provided demonstrated the robustness of the technology and the associated techniques summarized in Table 2.

The following case histories illustrate the use of the technology on a worldwide basis: 6 Rockies, USA. This well located in Wyoming contained 19 frac stages. Ten deep stages were fractured with HTNCC tagged intermediate density ceramic proppant, one shallow stage with tagged lightweight ceramic proppant and the remaining eight shallower stages with untagged proppant. The well was originally logged with a CNT prior to the frac operation, again after the frac job had been completed and after several months of production. Wellbore fluids varied in the wellbore on each of the log runs and the borehole size and the casing and liners present differed over the entire logged interval. Hence, for interpretation, the well was partitioned into several zones with constant wellbore data.

Data from this well is shown in Figure 2.

6 China. In this second example details of which are shown in Figure 3, the well was perforated from x278-286m. Fracturing occurred down 5-1/2â&#x20AC;? casing using a cross linked fluid system with 54,000 lbs. of 20/40 sand followed by 26,000 lbs. of a 20/40 light weight ceramic containing a HTNCC. 6 South Texas, USA. Results of this well are shown in Figure 4. The formations in this example have low permeabilities (<1 millidarcy) and porosities generally in the 10-15 per cent range. The well was fractured in several sets of perforations using 300,000 lbs. of 20/40 light weight ceramic proppant tagged with a HTNCC. The well was producing 9.8mmcf, 111 bopd, and 30 bwpd during the post-frac logging operation after a 12 day interval between the pre and postfrac logs.

6 South America. Results from this well are illustrated in Figure 5 and 6. This well was in Putumayo basin, Colombia and targeted sands having 44 and 156 ft. of gross thickness with porosity ranging between 8.3 per cent and 17.2 per cent and absolute permeability between 10 and 1,500 mD. Frac height is a most critical design parameter to control in Juanambu but after 20 fracture jobs evaluation proved inconclusive, so the HTNCC proppant technology was used with positive results.

Conclusions 6 The non-radioactive traceable proppant and logging methods for fracture

6 6

6

6

6 6

6

height measurement do not affect mechanical strength, conductivity, durability or density of the particles.

The neutron capture compound does not deteriorate so logging may be done at any time in the well life.

One interpretation technique which has been successfully modeled and field tested compares pre-frac CNT log count rates with corresponding post-frac CNT values.

A second modeled/field tested technique utilizes only post-frac CNT data, wherein the observed CNT post-frac count rates are compared with those computed from the N/F count rate ratio for use when well parameters vary over time.

Modeling data has also indicated that comparison of PNC captured data can be effective in locating proppant tagged with high thermal neutron capture cross-section absorbers.

This new proppant has been successfully employed worldwide Successful cases performed in difficult conditions, derived from changes in the wellbore and formation environment, demonstrate the robustness of the technology and interpretation techniques.

None of these techniques employ radioactive tracer material, making them acceptable under all environmental, operational and safety considerations. â&#x2013;

This paper was prepared for presentation at the SPE/EAGE European Unconventional Resources Conference and Exhibition held in Vienna, Austria, 2022, March 2012.

86 Oil Review Middle East Issue Three 2012

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OIL REVIEW SPOKE exclusively to Brice Bouffard, Vice President Petroleum Consulting, Weatherford and Bob Kuchinski, Business Development Manager MENA, Weatherford about the recent launch of the company’s new business unit Petroleum Consulting and what this will mean for the petroleum industry as a whole.

After eight months of building up its core team and strategy, Weatherford launched its new unique business proposition, at the Geosciences Conference and Exhibition (GEO) 2012 in Bahrain, namely its Petroleum Consulting business unit which will provide services to operators worldwide in the geoscience and engineering domain.

development planning, production optimisation, well engineering and project management.

Kuchinski commented: “We have a lot of really good technology coupled with great field technicians that can operate them. We have skilled experts and professionals in virtually every area, whether it be seismic, micro-seismic, sedimentation etc.”

Bouffard has been busy over the last eight months creating the foundations for the Petroleum Consulting business unit by “putting the people and team together and creating the right environment for the team to work under.”

Importantly for Bouffard the new unit will lead to meaningful training and development of the next

Brice Bouffard

Petroleum Consulting service through its dedicated global network of geosciences and engineering professionals can provide expert advice on the critical decisions to maximize recovery in conventional and unconventional reservoirs.

The big advantage of the new service is the flexibility and breadth it can offer. Weatherford can tailor their offering to the specific needs of the client.

“That is why having this knowledge and global footprint can be such a powerful tool offered to clients. We are able to leverage off our experiences around the world and give our expert opinion. We bring this knowledge and tools to the client. They will better understand their own reservoir and ultimately produce more oil,” Kuchinski added.

This can range from Petroleum Consulting providing advice via Weatherford’s global network of 38 geosciences laboratories and labs at wellsite that offer a range of formation evaluation services.

Or clients acquiring real-time logging data with LWD technologies that works in the most extreme operating environments.

Solution

The global launch of the new service in Bahrain demonstrated that Weatherford is: “committed to the long term development of the Petroleum Consulting business in order to provide industry leading consultative advice in alignment with client drivers. Its growth will be driven based on a three pronged strategy: investment in expertise and their rounded development, innovation in differentiated technologies and close collaboration with its clients,” Bouffard said.

Kuchinski explained: “Petroleum Consulting is the newest product line in our Reservoir and Formation Evaluation services.” It will offer clients integrated formation evaluation and well engineering support and consultancy.

“It is set up to bring more brain power behind all of these formation evaluation services that we run. Petroleum Consulting is bringing more of the interpretative brain power to our offering. It is this new emphasis on partnership with clients that will be a real focus of the new business unit,” added Kuchinski.

generation of geologists and engineers. This new unit will allow Weatherford to provide fulfilling career paths for professionals working at the company.

“Our ultimate goal is to double our headcount in the next three to four years. We will be able to offer this service to our employees across our global organisation,” he said.

The two key skills that will be emphasized during training will be firstly to encourage and develop creativity and the ability to innovate. The second is the ability to collaborate and work in a team.

“We are training the new Petroleum Consulting members around these two key skills as we believe these are key functions and requirements demanded by our clients. We want our clients to have the best team working with them,” Bouffard said.

Petroleum Consulting draws on the combined strength of its product portfolio which spans the life cycle of the well by providing integrated reservoir data solutions, well engineering and project management, production optimisation and well abandonment.

Skilled experts Petroleum Consulting will operate on Weatherford’s global footprint. There are currently 300 employees worldwide, including domain experts in the area of unconventional resources, geomechanics, field

Extreme environments Whether a client wants to reduce reservoir uncertainty, process data more efficiently or protect the integrity of their well in any environment the

Ultimately the new consulting service will enable clients to understand their reservoir better, maximise production and optimise capital spent.

Both Bouffard and Kuchinski emphasised the client focused nature of the new service.

Petroleum Consulting will not only help the client understand their reservoirs better but it will be a collaborative approach whereby feedback from the clients will help Weatherford improve its current and future capabilities.

“It is really a partnership that we are developing,” Kuchinski pointed out.

There will be Petroleum Consulting teams developed across all regions that Weatherford operates in. According to Bouffard, Petroleum Consulting’s ambition is to make it the preferred technical interface between Weatherford and its clients. “It is to become the arm which understands what our clients require on a reservoir standpoint and come up with a proper solution for our clients.”

Kuchinski pointed out that the new unit will work with the client early on in the work flow as it will it give the client better access to Weatherford’s relevant technologies based on clients’ challenges and drivers.

“The need for knowledge across the industry is palpable and clients are clamouring for it and Petroleum Consulting will provide the answer,” Bouffard noted.

“We look forward to disseminating our knowledge to the global client base. The demand currently from our clients regarding unconventional resources is enormous. The hunger to know more is growing,” he said.

Bouffard concluded by saying that having just started to interface with clients: “we have already had a very positive feedback. This is very encouraging. The focus in 2012 is to make this a sustainable, long term business.”

Oil Review Middle East Issue Three 2012 87

Technical Focus

Petroleum Consulting brings client collaboration to new heights

Information Technology

S17 ORME 3 2012 IT_Layout 1 05/04/2012 15:07 Page 88

Sami Suheil, CEO of Monitor, talked to Oil Review about the growth in digital oil fields in the region and how vMonitor’s wireless solutions are the best fit for these markets.

Growth of

digital oil fields A

CCORDING TO SUHEIL the evolution of the Digital Oil field (DOF) has been a slow process since being identified years ago due to many obstacles mainly linked to uniform data exchange platforms and in some cases the limitations of technology used in the oil field.

With the evolution of OPC and other integration platforms and the advances in hardware and software technology has finally changed all this and DOF has become a reality.

Suheil explained that as DOF requires vast amounts of data from the field in near “real time” for slower and faster loops it was the advances in radio technology and abundance of bandwidth and QoS in communications that has allowed data to be transported with high reliability to the central repositories.

While, advances in hardware platforms whether on the embedded micro processors or on powerful servers helped quality control data and perform required analysis in almost real time. Emerging uniform open standard communications protocols such as OLE for Process Control, OPC, allowed systems to share data and exchange data to allow different systems to perform diverse analysis and converge into a needed decision.

“The emergence of all these technologies together is allowing the vision become reality and allowing people to execute their own workflows in an automated process and permitting knowledge and data sharing among different interested parties instead of previously having that data compartmentalised in silos,” said Suheil.

Opportunities Suheil discussed the opportunities in the DOF arena in the region.

“The Middle East has had it easy over the years except for some particular markets, but as awareness of resource optimisation and the capabilities to enhance recovery from reservoirs and the shortage in qualified resources is pressing oil companies to engage the industry in implementations of DOF projects.”

He pointed out that challenges such as water breakthrough and mature assets are imposing the acceleration of need for knowledge sharing, better data management and converting that data into knowledge and smart decisions. The opportunities are vast and the needs are justified with the operators are facing.

“DOF is much more than a trend in the industry, it is the way we ought to be doing business. That has dawned on everyone,” added Suheil.

DOF or Smart Oilfields have different levels of smartness and the industry has been evolving towards DOF through many initiatives, some are through basic monitoring and telemetry which has been around for many years, some are going beyond monitoring into remote operations and others are progressing yet further allowing Collaborative Work environments and data/knowledge sharing across their assets and resources.

In the region there are many companies that have been doing a lot of smartness for many years such as PDO and Saudi Aramco and others who are piloting several technologies starting with smart completions up to wellhead through the network into processing facilities identifying bottlenecks and optimising every process along the way.

Wireless impact Suheil elaborated on the benefits that vMonitor’s products can bring to the DOF arena.

“Our whole product line and growth strategy is cantered around the DOF enablement and all our acquisitions are around the value loop of the DOF,” said Suheil. He added: “The solutions we are addressing are to provide oil and service companies with the components and solutions that will help them realise the end to end solution or the tools that will allow the user to select the

88 Oil Review Middle East Issue Three 2012

Sami Suheil, CEO of Monitor

“DOF is much more than a trend in the industry, it is the way we ought to be doing business. That has dawned on everyone“ missing components to be able to close the loop.”

In early 2011, vMonitor acquired a reputable production choke company with 27 years experience to provide the control element in the field, similarly the company is going at the different elements of the value loop and addressing our products and solutions to complement the need in the market.

Wireless is a major component of these products. “vMonitor has focused on the upstream market and has differentiated ourselves by carving our own niche focusing on true upstream applications with the longest range wireless sensor and true wellhead applications.” vMonitor has also focused on providing the industry the enablers of DOF with an end to end solution starting with long range wireless sensors allowing the least amount of gateways in the field with open communications protocols reporting to a fit for application SCADA system with a flexible polling engine and an integration middleware platform based on an OPC broker to be able to pass and exchange data with different third party applications and legacy platforms and databases.

S17 ORME 3 2012 IT_Layout 1 05/04/2012 15:07 Page 89

Information Technology vMonitor products in action on a ADMA-OPCO installation just off the Abu Dhabi Coast (Zakum Field)

Innovation Suheil talked about new product launches planned for later this year, including products that will comply with the emerging standards and others that address applications using our product line and adding some local intelligence on the product taking advantages of the advances in microprocessor capabilities. vMonitor launched a few products last year amongst which is an orifice based single Phase flow computer that uses some petroleum engineering correlations, some PVT data and a well test for calibration to estimate the multiphase flow.

It is a great tool for doing allocation in real time versus using the well test to do allocation for the well over the period between well tests.

“Our methodology in this product and other products and solutions we have on the drawing board is to go by the 80/20 ratio, providing the industry with a solution that can address 80 per cent of the functionality for 20 per cent of the cost,”said Suheil.

“Our whole product line and growth strategy is cantered around the DOF enablement and all our acquisitions are around the value loop of the DOF” Projects vMonitor has been awarded several big projects over the last year mainly in Kuwait, Venezuela, and other markets where mass commercial roll outs are being considered with the client.

“Kuwait is a tremendous market and a really exciting market.”

KOC has a wide range of reservoirs and have all types of crudes and production. On top of that KOC is really adopting the holistic approach to DOF and is starting from the grounds up by collecting data from all brown fields, providing their users access to that data and allowing different vendors to highlight their technologies by analysing that data and recommending solutions to better optimise the process and enhance recovery.

“KOC is trying to implement a vendor agnostic approach to the process of operating and managing their assets,” he added.

Suheil gave his outlook for the industry in 2012 saying: “It is promising to be another good year for demand and a momentum building year with global market health indicators leading to more automation and implementation of DOF through out several organisations, the instability in the region in particular and Europe’s economic troubles can have an impact on the demand side of the equation due to supply routes and higher prices.” n

Oil Review Middle East Issue Three 2012 89

Information Technology

S17 ORME 3 2012 IT_Layout 1 05/04/2012 15:07 Page 90

EtherNet/IP module added to flowmeters EMERSON PROCESS MANAGEMENT introduced an EtherNet/IP Module for Micro Motion Coriolis meters. Suitable for new or retrofit installations, the module is compatible with all Micro Motion Coriolis flowmeters, and is suitable for hazardous areas.

Access to the multivariable data enabled by the module allows for increased productivity and fast process insight with control system access to flow, density, temperature and many other parameters.

Compact and easy to install in less than 30 minutes, the EtherNet/IP Module can be mounted in the control cabinet, removing the need to run Ethernet cabling out to the field. The module web browser provides network access to a powerful configuration and diagnostic interface, enabling a full range of remote activities. This includes running Smart Meter Verification, which determines Coriolis meter performance without stopping the process or interrupting the flow.

The module enables quick and cost effective access to the growing number of EtherNet/IP plant-wide networks and adds to the range of communication interface options available with Micro Motion Coriolis flowmeters. These include DeviceNet, PROFIBUS DP, Modbus, FOUNDATION fieldbus, and PROFIBUS PA in addition to the traditional interfaces of 4-20 mA frequency and HART. The EtherNet/IP Module is suitable for DIN Rail mounting and is ODVA Certified. The software provided enables Micro Motion Coriolis flowmeters to be easily configured remotely via the plant network.

Ethernet/IP is an open, industry-standard networking technology supporting connections to a wide range of devices including motor starters, sensors, controllers and HMI devices. Ethernet/IP supports non-industrial and industrial communications on a common network infrastructure.

Imaging-while-drilling technology launched by Schlumberger SCHLUMBERGER HAS LAUNCHED MicroScope 475, which is a highresolution resistivity and imaging-while-drilling service.

On a single collar, this logging-while-drilling service provides highresolution laterolog resistivity and full borehole images in conductive mud environments. The technology provides key information for formation evaluation, well placement and fracture identification.

The MicroScope tool acquires focused laterolog resistivity measurements and images at four different depths of investigation with azimuthal sensitivity. These measurements are essential for calculating reserve estimates, placing horizontal wells and optimising MicroScope completion design. being installed "Optimal placement of the borehole in the reservoir, accurate evaluation of formation properties and identification of geological features that impact producibility are key elements of a successful well," said Andy Hendricks, president, Drilling & Measurements, Schlumberger.

MicroScope has been in development for four years during which it has being tested rigorously and deployed worldwide. The service addresses challenges in unconventional shale plays, carbonate and clastic reservoirs. The majority of the testing took place in the carbonate projects in the region.

90 Oil Review Middle East Issue Three 2012

Digitalcore and Numerical Rocks merge IN AN EXCLUSIVE interview with Oil Review Middle East, Odd Hjelmeland, CEO of Norway’s Numerical Rocks, and Victor Pantano, CEO of Australia’s Digitalcore, spoke about their decision to merge the companies and create a global leader in the field of digital rock analysis.

“I was previously CEO of the ResLab Group so I know all about characterising core material conventionally” explained Hjelmeland. “It can take a long time to run complex experiments. I believe that digital techniques will complement physical experiments and give more possibilities for sensitivity analysis or what-if-scenarios. Numerical Rocks has spent eight years perfecting the process. Our e-Core™ software imports images or a detailed description of the rock sample and, using knowledge of geology and reservoirs, we can accurately predict rock properties and fluid flow characteristics.”

Dr. Odd Hjelmeland and Dr. Victor Pantano shake hands after the merger announcement.

“Digitalcore has been focussed on providing the best possible images“ said Pantano. “In more than ten years of research at the Australian National University, we have found that the only way to get the image quality we need in a timely manner is to build bespoke micro-CT scanners incorporating unique capabilities such as out HeliScan™ helical scanning technology.

Equally important, we can combine 2D and 3D images at various resolutions using our VoxelPerfect™ software to further improve the rock model.”

Odd explained the drivers behind the merger. “While the opportunities are immense, each of us is located on the fringes of the international oil and gas business – we in northern Norway and Digitalcore in southern Australia.

Most of our prospective clients are locations in the Middle East, the Americas, Europe and in southern Asia. We want to bring a local presence to these markets so that companies will find it easier to do business with us.”

“Digitalcore already had plans to open laboratories in the Middle East, primarily to serve specific clients. With the merger, we also gain a significant influx of additional capital which will fund our growth, especially in the Middle East and the Americas. Our intention is to have a fully commercial laboratory running in the Middle East within one year.”

“This is a service business, so despite the advanced technology and software, the goal is to provide a faster and more standardised set of client services that are delivered on time and offer incomparable value-for-money” added Pantano. “We will still undertake specialist projects, where we are working on the boundary of current technology. There are lots of challenges, such as developing a better understanding of wettability and how it varies throughout the reservoir. Digitalcore has been making great advances in this area and we are all excited to see how those will result in an even more accurate understanding of how oil and gas reservoirs perform.”

Summing up, Hjelmeland added “Our teams are alike in many ways.

Among our joint staff we have internationally recognised experts, with many years of industry experience, and an in-depth understanding of the issues and challenges of accurately imaging and modelling reservoir rocks. The main challenge will be in establishing overseas laboratories, training new technicians and analysts, and continuing to provide a quality service based on speed, accuracy and complete data transparency.”

S17 ORME 3 2012 IT_Layout 1 05/04/2012 15:07 Page 91

THE 4 TH SAUDI ARABIA INTERNATIONAL OIL & GAS EXHIBITION

24-26 SEPTEMBER 2012 DAMMAM, KINGDOM OF SAUDI ARABIA WWW.SAOGE.ORG

S17 ORME 3 2012 IT_Layout 1 05/04/2012 15:07 Page 92

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 Oil

Gas

LAST YEAR

Oil

Gas

Misc

Total

Misc

Oil

Gas

Misc

Total

ABU DHABI

19

2

0

21

1

BAHRAIN (1)

4

0

0

4

0

0

0

18

2

0

20

0

0

4

0

0

CYPRUS (1)

0

0

0

0

0

-1

4

0

0

1

0

1

DUBAI

1

0

0

1

0

0

0

1

0

0

1

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)

0

3

0

3

0

1

-1

0

2

1

3

JORDAN

0

0

0

0

0

0

0

0

0

0

0 32

Middle East

KUWAIT

25

6

0

31

-2

1

0

27

5

0

OMAN

40

13

0

53

1

1

0

39

12

0

51

PAKISTAN

5

9

0

14

0

0

0

5

9

0

14

QATAR

5

3

0

8

0

0

0

5

3

0

8

SAUDI ARABIA

45

29

0

74

-4

1

0

49

28

0

77

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

0

0

0

2

0

0

2

173

65

0

238

-5

3

-1

177

62

1

240

YEMEN TOTAL

North Africa ALGERIA (1)

25

6

1

32

5

-1

0

20

7

1

28

EGYPT

52

21

0

73

0

1

0

52

20

0

72

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

0

0

1

1

-2

0

0

2

0

1

3

TOTAL

77

27

2

106

3

0

0

77

27

1

105

Source: Baker Hughes

92 Oil Review Middle East Issue Three 2012

S18 ORME 3 2012 Arabic_Layout 1 05/04/2012 15:53 Page 93

S18 ORME 3 2012 Arabic_Layout 1 05/04/2012 15:53 Page 94

S18 ORME 3 2012 Arabic_Layout 1 05/04/2012 15:53 Page 95

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Discover global best practices and technologies in heavy oil exploration and production at this inaugural event t #FOFm U GSPN B QFFS TFMFDUFE UFDIOJDBM QSPHSBN t 5BLF BEWBOUBHF PG DPOUJOVJOH FEVDBUJPO PQQPSUVOJUJFT t 7JTJU UIF FYIJCJUJPO BU UIF (MPCBM 1FUSPMFVN 4IPX

12–14 June 2012 BMO Centre // Calgary, Alberta, Canada www.spe.org/events/ihoc

Held in conjunction with

Society of Petroleum Engineers

www.spe.org

S18 ORME 3 2012 Arabic_Layout 1 05/04/2012 15:53 Page 98

19th International

CASPIAN OIL & GAS Exhibition and Conference Incorporating

Refining & Petrochemicals

5-8 June 2012 Baku • Azerbaijan

www.caspianoil-gas.com

LEADING OIL & GAS EVENT IN CASPIAN REGION

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

S18 ORME 3 2012 Arabic_Layout 1 05/04/2012 15:53 Page 99

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Country Representative Telephone Fax Email Country Representative Telephone Fax Email China Wang (86)10 China WangYing Ying (86)108472 84721899 1899 (86) (86)10108472 84721900 1900 ying.mathieson@alaincharles.com ying.mathieson@alaincharles.com India Tanmay Mishra (91) 80 65684483 (91) 80 40600791 tanmay.mishra@alaincharles.com India Tanmay Mishra (91) 80 65684483 (91) 80 40600791 tanmay.mishra@alaincharles.com Italy Camilla Capece (39) 06 97619380 camilla.capece@alaincharles.com Italy Camilla Capece (39) 06 97619380 camilla.capece@alaincharles.com Nigeria Bola (234) bola.olowo@alaincharles.com Nigeria BolaOlowo Olowo (234)8034349299 8034349299 bola.olowo@alaincharles.com Russia Sergei (7495) 540 5407564 7564 (7495) (7495)540 5407565 7565 mne@acpmos.ru mne@acpmos.ru Russia Sergei Salov Salov (7495) South Africa (27) South Africa Annabel Annabel Marx Marx (27)218519017 218519017 (27) (27)46 46624 6245931 5931 annabel.marx@alaincharles.com annabel.marx@alaincharles.com Qatar Saida (974) saida.hamad@alaincharles.com Qatar SaidaHamad Hamad (974)55745780 55745780 saida.hamad@alaincharles.com UK Steve (44) 7676 (44) (44) 20 20 79730076 79730076 stephen.thomas@alaincharles.com stephen.thomas@alaincharles.com UK SteveThomas Thomas (44)20 20 7834 7834 7676 USA Michael (1) 203 7447 michael.tomashefsky@alaincharles.com USA MichaelTomashefsky Tomashefsky (1) (1)203 203226 226 2882 2882 (1) 203 226 226 7447 michael.tomashefsky@alaincharles.com

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ADVERTISERS INDEX Company ................................................Page Aban Air Cooler Co. ..............................................93 Adghal Oilfield Supplies LLC ................................12 Al Mansoori ..............................................................15 ALAA Industrial Equipment Factory ....................14 Alderley FZE ............................................................66 Asturi Metal Builders (M) SDN BHD ....................71 Aveva Solutions Ltd ................................................43 Bapco ......................................................................103 Bredero Shaw ..........................................................13 Castrol Marine Limited ..........................................30 Chevron ....................................................................10 Draeger Safety ........................................................22 Duferco ......................................................................27 Emerson Process Management ..............................3 Emirates ....................................................................19 Euroblast Middle East ............................................68 Europoles Middle East (LLC) ..................................48 Expotim International Fair ORG. INC (Basra Oil & Gas 2012) ..........................................94 Fracture Technologies Ltd ....................................81 Gates Engineering and Services ..........................45 GRACO BVBA ..........................................................40 Hi-Force Ltd ..............................................................23 Honghua Golden Coast Equipment FZE ..............20

3

Hydroflow Pump Rental Est......................................8 International Exhibition Services Srl (SAOGE 2012) ............................................................91 ITE Group Plc (Caspian Oil & Gas 2012) ..............98 Jotun Paints U.A.E. Ltd (LLC) ..................................7 Kaeser Kompressoren FZE ....................................57 Litremetre ................................................................22 Marelli Motori S.p.A. ................................................2 Megarme ..................................................................33 Metscco Heavy Steel Industries Company Limited ....................................................65 Mimo Contracting ..................................................47 Mott MacDonald Ltd. ..............................................53 Nexans ......................................................................21 Oil Country Tubular Ltd (OCTL) ............................59 Oman Cement Company ........................................35 OutoKumpu Armetal ..............................................51 Peri L.L.C. ..................................................................75 Petrotech Enterprises (LLC) ..................................39 Prakash Steelage Ltd. ............................................63 Rittal Middle East FZE ..........................................32 Sabin Metal Corporation ........................................29 Safety Technical Services Co. Ltd. ......................49 Saga PCE Pte Ltd ....................................................37 Saudi Leather Industries Company Ltd. ..............60

Saudi Steel Pipe Co â&#x20AC;&#x201C; Dammam ..........................83 Schlumberger Oilfield Mktg Communications ..........................................28 Schlumberger Technical Services, Inc. ................4 Schneider Electric IT Logistic Europe ................61 Shanfari Group of Companies ..............................41 Shree Steel Overseas FZCO ....................................6 Sin Hiap Chuan Hardware and Engineering Pte Ltd ................................................46 Society of Petroleum Engineers (Heavy Oil Conference 2012) ................................97 Southern California Valve ......................................24 Specialized Oilfield Products ..................................9 Stevens Supply International (Hardbranding Solutions) ........................................25 Stevens Supply International (Duraband)............79 Suraj Limited ............................................................33 Syscom18 ..................................................................89 T.D. Williamson SA ..................................................69 Technip - Region Middle East ..............................73 Tenaris ......................................................................17 TMK ............................................................................77 United Metallurgical Company / JSC OMK ......54 VEOLIA WATER ......................................................100 VF Imagewear/Bulwark ........................................67

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