Oil Review Middle East issue 3 2012

As the world’s largest oil and gas producing region,the Middle East is a natural magnet for drillers and akey location in the global rigs market.See page 72

PDO deliversanother

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Oil R

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Turmoil constrains regionalinvestment

Bahrain in gas import talks

Oil reserves not for release - IEA

Yemen facing the prospect offurther unrest

Feedstock shortage threatenspetrochemical producers

Corrosion inhibitors ‘go green’

The benefits of wireless sensornetworks

Hydraulic fracturing - reducingenvironmental risks

The growth in digital oilfields

Vol 15Issue Three 2012

www.oilreview.me

UK £10, USA $16.50

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

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Oil Review Middle East Issue Three 2012 5

Editor’s noteOMAN’S OIL AND gas reserves may not quite match those of fellow Gulfproducers but that has not stopped the Sultanate from making the most ofwhat it does have. The country is still a major oil and gas exporter in its ownright, though not a member of the OPEC. And what a job PetroleumDevelopment Oman (PDO) has done in recent years by turning aroundOman’s dwindling production volumes, to restore output to former levelsand pocket precious more income for the government as it continues toexpand and diversify the economy beyond hydrocarbons. Other regionalproducers could learn a lot from PDO’s upstream engineers who are meetingthe challenge of complex reservoir systems and ageing fields head on toboost the nation’s oil and gas production year-by-year.

ColumnsIndustry news and executives’ calendar 6

AnalysisYemen 16Further attacks on the Yemen’s oil and gas infrastructure are inevitable, according toexperts at Exclusive Analysis.

Outlook 18GL Noble Denton and the Economist Intelligence Unit have launched a new report.

Exploration & ProductionDevelopments 22The latest exploration and production news from around the region.

GasAnalysis 30Abu Dhabi announced plans to build an import terminal for LNG at Fujairah.

PetrochemicalsOutlook 36A shortage of natural gas feedstock threatens the region’s dominance as the mosteconomical petrochemicals producer.

PDO ReviewProfile 41Upstream engineers at Petroleum Development Oman (PDO) are confronting thechallenge of complex reservoir systems and ageing fields head on to boost thesultanate’s oil and gas production.

Exhibitions and ConferencesOil and Gas West Asia 50Oman’s oil and gas sector remains quite vibrant, and the forthcoming OGWA event willhighlight the sultanate’s expanding energy plans.

Caspian Oil & Gas Exhibition 55Azerbaijan has capitalised on its large hydrocarbon resources and continues toencourage foreign direct investment in its oil and gas industry.

ADIPEC 2012 55Canadian companies already have an eye on the region’s biggest oil and gas event.

Technical FocusInnovations 57Introducing some of the latest available technologies for the oil and gas sector.

Corrosion Prevention 68The development of a new class of environmentally acceptable corrosion inhibitors foroil and gas fields is now a reality.

Rigs 72The region continues to provide a reliable source of work for drillers despite global oildemand fears.

Oman continues to defy the oddswhen it comes to production.Photo courtesy of PDO

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

PDO deliversanother

productionboost

15Se

rvin

g th

e re

gion

al

oil &

gas

sec

tor

sinc

e 19

97

year

s

See us at these events

Turmoil constrains regional

investment



Yemen facing the prospect of

further unrest

Feedstock shortage threatens

petrochemical producers

Corrosion inhibitors ‘go green’

The benefits of wireless sensor

networks

Hydraulic fracturing - reducing

environmental risks

The growth in digital oilfields

Vol 15Issue Three 2012

www.oilreview.me

UK £10, USA $16.50

Contents

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

Magazine Sales Manager: Laetitia Mariani Tel: +971 4 448 9260, Fax: +971 4 448 9261, Email: [email protected]

Country Representative Telephone Fax Email

China Wang Ying (86) 10 8472 1899 (86) 10 8472 1900 [email protected] Tanmay Mishra (91) 80 65684483 (91) 80 40600791 [email protected] Bola Olowo (234) 8034349299 [email protected] Sergei Salov (7495) 540 7564 (7495) 540 7565 [email protected] Africa Annabel Marx (27) 218519017 (27) 46 624 5931 [email protected] Saida Hamad (974) 55745780 [email protected] UK Steve Thomas (44) 20 7834 7676 (44) 20 79730076 [email protected] Michael Tomashefsky (1) 203 226 2882 (1) 203 226 7447 [email protected]

www.oilreview.meemail: [email protected]

Head Office: Middle East Regional Office:Alain Charles Publishing Ltd Alain Charles Middle East FZ-LLCUniversity House Office 215, Loft 2A11-13 Lower Grosvenor Place P.O. Box 502207London SW1W 0EX, United Kingdom Dubai Media City, UAETelephone: +44 20 7834 7676 Telephone: +971 4 448 9260 Fax: +44 20 7973 0076 Fax: +971 4 448 9261

Production: Donatella Moranelli, Nasima Osman, Nick Salt, Jeremy Walters and Sophia White -Email: [email protected]

Subscriptions: Email: [email protected]

Chairman: Derek Fordham

Printed by: Emirates Printing Press, Dubai© Oil Review Middle East ISSN: 1464-9314 Serving the world of business

Wireless Technology 76Honeywell Process Solutions says a growing emphasis on wireless technology can bringmajor benefits to the oil and gas sector.

Wireless Sensor Networks 78Gianni Minetti, President and CEO of Paradox Engineering SA, examines wireless sensornetworks and their applications for remote and condition monitoring of oil and gassites.

Hydraulic Fracturing 82Why propped hydraulic fracturing reduces environmental risks.

Interview 87Oil Review recently spoke to Brice Bouffard, Vice-President of Petroleum Consulting,Weatherford and Bob Kuchinski, Business Development Manager, Weatherford aboutthe launch of the company’s new business unit, Petroleum Consulting.

IT & CommunicationsDigital Oilfields 88Sami Suheil, CEO of Monitor spoke to Oil Review about the growth of digital oilfields inthe region.

News and Developments 90The latest communications and IT news from the regional oil and gas sector.

Arabic SectionNews 5Analysis 11


Oil Review Middle East Issue Three 2012

THE GCC'S HYDROCARBON reserves areestimated to be worth around US$65 trillion atcurrent export prices, based on new analysis fromQNB Capital. This is almost a third of the US$200trillion value of world oil and gas reserves.

To put US$65 trillion in context, it isequivalent to 47 times the GCC's estimated GDPin 2011, or 93 per cent of global GDP. It is also125 times the estimated US$521 billion that theregion's governments received in oil and gasrevenue during 2011.

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

Splitting down the total hydrocarbon reservesby country shows that Saudi Arabia represents

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

These estimates are only indicative ashydrocarbons prices are volatile and hard topredict given that they are influenced by anumber of factors. These factors include worldeconomic growth, geo-political risk, energyefficiency and technological advancements. If thelower hydrocarbon prices recorded in 2009, whichcan be seen as a worst case scenario, were usedin QNB Capital's calculation, then the reserveswould be worth (only) US$42 trillion.

As gas prices vary considerably betweencountries, unlike oil prices, QNB Capitalassumed a gas price of about US$7.5 perthousand cubic feet, an average of US,European and Asian pipeline and liquefiednatural gas (LNG) import prices.

This is a reasonable estimate of what gas iscurrently worth to the main importing countries. Atthese prices, it would cost about $40 to purchase avolume of gas that produces the same amount ofenergy as a barrel of oil. Therefore, exported gas isworth just over a third of the oil price, which isestimated at US$109 a barrel in 2011.

Gas can be regarded as even cheaper relativeto oil if environmental costs are taken intoaccount as it is a cleaner burning and moreefficient fuel. Therefore, it is possible that, astechnology makes it cheaper and easier totransport and use gas (including in vehicles), itsdiscount to oil may reduce. This would increasethe value of gas reserves relative to oil reserves.

QNB Capital also stated that its calculationsmay be an underestimate because new reserveswill probably be found. Also, technologicaladvances and high prices will make a largershare of the existing in reserves commerciallyexploitable.

THE PREVAILING UNREST in certain areas of the Middle East and North Africa,along with rising costs, will hamper investment in the upstream hydrocarbonsector, a report by the Arab Petroleum Investment Corporation (Apicorp), anaffiliate 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'sextractable oil deposits, investment in hydrocarbon projects by MENA countriesis estimated at only around US$2.7 trillion until the year 2035, a fraction of thetotal global energy projects worth nearly US$37.5 trillion, the report noted.

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

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

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

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

IRAQ HAS APPROVED a plan to expand its oil export routes by addingcapacity from its northern fields and building a pipeline to ship oil from

southern fields to Ceyhan inTurkey, a governmentspokesman said. Thecontingency plan was set by thegovernment's energy andeconomic committee to dealwith any potential crisis shouldIran close the Strait of Hormuz,which would halt about 80 percent of Iraq's oil exports. Iranhas threatened to close theStrait of Hormuz, used for a thirdof the world's seaborne oil trade,if Western moves to ban Iranian

crude exports crippled its energy sector. 'Short and mid-term plans willbe through boosting crude pumping and upgrading export capacity viaCeyhan port in Turkey. Also to increase the number of trucks that areshipping crude,' government spokesman Ali al-Dabbagh said.

6

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Regional oil and gas reserves worth US$65 trillion

Unrest constrains regional investments Iraq approves Hormuz plan

Strait of Hormuz - will Iran close it?


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8

LAMPRELL ANNOUNCED THAT its revenues increased 127.8 per centto US$1.14 billion last year. Its adjusted netprofit was up 10.8 per cent to US$73.8mnfrom US$66.6mn in 2010.In 2011 the group was awarded a recordUS$1.1 billion worth of contracts, thecompany said."We're very pleased with the numbers,"said CEO Nigel McCue, adding that theacquisition of Maritime Industrial ServicesCo (MIS) had significantly contributed toconsolidating the company's position as amarket leader in the provision ofcontracting products and services in the oil,gas, and renewables industry.

The acquisition of Maritime Industrial Services Co was completed inJuly 2011, increasing Lamprell's yard spaceto 925,000 square metres and the quaysideto 2.2 km, which has helped expand thegroup's service offering, customer base andgeographical range. Last year the group undertook 43 jackup rigupgrade and refurbishment projects.Contracts secured an additional five jackuprigs, giving the group's eight new build rigsunder construction at the end of the year.In the renewable sector for wind farminstallation vessels, McCue said thatLamprell delivered two vessels and isexpected to deliver three more this year.

OIL REVIEW SPOKE to Bjarne-Andre Asheim,Regional Business Unit Manager Oil, Gas andPetrochemicals for ABB in the Middle East aboutthe growing demand for greater integration ofautomation in the hydrocarbon sector and whatABB is doing to bring this about. Asheim explainedthat ABB was trying to use its considerableexperience to bring innovative products to the restof 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 moreand more focus within the electrification part.”

Asheim argued that the increased focus onenergy efficiency within other industries is nowcoming to the oil, gas and petrochemical market.

“We can see that there can be huge savings justby applying the existing technology we have alreadytoday,” he said. “We can use this in the oil, gas andpetrochemical market and huge savings can befound, especially in the Middle East market.”

Asheim discussed the different oil and gassector trends and said that there is currently agrowing emphasis on the greater integration ofelectrification and automation.

“This will result in more and more integration ofdata and a greater use of smart applications all theway from the transmitters to the ERP systems,” hesaid. “The full integration of data from differentsystems will soon be a requirement in all oil, gasand petrochemical plants.

“ABB offers solutions within the whole valuechain and it is where we can provide a huge savingto our clients. For instance in stressful operationsyou need to provide solutions and consolidated orpre-treated data to the operator that makes himmore effective in his work. “The market for operatoreffectiveness and high performance HMI (humanmachine interface) is going to be a differentiator forthe future. That is why we have focused a lotaround what is basically all about empowering theoperator. We develop more and more solutions forthis that become smarter and smarter.”

Asheim stated that the whole of the Middle East isABB’s target market, with the UAE, Saudi Arabia, Qatar,and Iraq seen as key markets. He also discussed theimportance of the growing petrochemical sector.

“We had a major break through with the Sadaraproject which was a big win for us and it is great tosee the success,” said Asheim. “The solutions we

talked about and total integration will be there.Everything is going to be integrated with an ABBsystem and this will see our Saudi Arabiaoperations grow a lot.”

Asheim said that the growth of the gas marketover the last few years will be increasinglyimportant for the company.

“GTL is now coming up which will be very excitingto see what the usage of this will be,” he said. “Gas isgoing to play a more and more important role.”

Asheim feels that digital oilfields “are veryinteresting and is a growing interest in the region.The digital oilfield integrated operations arebecoming more relevant when you go in from peakproduction to tail production. You want to get moreout of your reservoir and lower your costs.”

The EOR market is really picking up in SaudiArabia and Oman, which has been involved in thisarea for quite some time, has been able to getproduction levels up, making this remain a focus forOman. In the UAE it is a real focus and it willbecome a focus for Kuwait and Qatar in the future.

“We are in the best position for this market andwe have seen this in other regions and we have lotsof references for this. ABB is well positioned for EOR.”

www.lamprell.com


Greater automation and integration needed

Lamprell’s profits boosted by increase in orders

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THE NEXT STEPS for collaborative technology development in theMiddle East, which will include the launch of a joint industryproject this year, were proposed at a recent event which broughttogether 30 of the region’s largest oil players.ITF, a membership organisation of international oil and gasoperator and service companies, united more than 70 seniorprofessionals to establish a vision for collaborative oil and gastechnology research and development in the GCC (Gulf Co-operation Council). The not-for-profit technology facilitatorbrokered discussion between the parties to tackle the mostpressing technology barriers to accessing hydrocarbon reserves.The event was sponsored by Kuwait Oil Company and chaired byJames McCallum CEO and founder of Senergy, an energy servicescompany which has an operation in Abu Dhabi. Presentationswere given by ITF member companies including Kuwait OilCompany, Petroleum Development Oman, and Shell on theopportunities and some of the common challenges beingexperienced in the region. Ryan McPherson, ITF’s regional director in the Middle East andAsia Pacific said: “The event was a huge success in gaining buy-in from oil and gas companies and providing ITF with a cleardirective to move forward with a regional group to deliver thevision for collaboration within the GCC.“There has been a clear cultural change with oil and gascompanies willing to work together on the similar issues theyface. The group will convene again to build on this momentum anddefine the key technology challenges. We also aim to launch aninitial demonstrator project before the end of the year to tackle aregional technology challenge and prove how the ITF process canwork.”The next step will be to identify technology needs specific to theGCC region.

SAUDI ARABIA AND other Middle East oil exporters can be relied on to meetrising oil demand and there is no need for the release of crude fromemergency reserves, according to the head of the International EnergyAgency (IEA).

"Saudi Arabia and other Gulf countries said to the world that they willmeet demand if the demand is there," Maria van der Hoeven, executivedirector of the IEA, said on the sidelines of a conference in New Delhi. "Theyare reliable suppliers."

The Paris-based agency co-ordinated the release of 60mn barrels of crudeand oil products in June after Libyan output was disrupted by the uprisingagainst Muammar Gaddafi, sending prices higher. The IEA also made suppliesavailable during the 1991 Gulf War and after Hurricane Katrina struck rigs andrefineries in the Gulf of Mexico in 2005.

Another release of strategic reserves is not warranted at the moment, vander Hoeven said. "Stock releases are about disruption of supplies and there isno disruption of supplies," she said.

Saudi Arabia can increase crude production by as much as 25 per centimmediately if needed, oil minister Ali Al Naimi said recently, seeking to allaythe 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.


www.iea.org

12

THE STATE-OWNED IRAQINorthern Oil Companyhas signed a preliminaryagreement with BP toincrease the production ofKirkuk field to 580,000barrels per day (bpd) fromabout 280,000 bpd.

The undersecretary ofNorthern Oil CompanyHussein Allam said: "Theinitial agreement is partof a high-level plancarried out by the OilMinistry through theNorthern Oil Company to develop the production of the northern fieldsthrough a partnership contract signed with BP.

The Kurdistan Region opposes any oil contract to develop oilfieldslocated within the borders of Kirkuk province and other areas in whichownership is disputed between Baghdad and Erbil.

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

The disputes between Baghdad and Erbil go back to the contractssigned by the latter with global companies to develop the oil fields inthe Kurdistan Region. Baghdad says such contracts are illegal. The IraqiOil Minister Abdul Karim Luaibi said recently that the country isstudying the proposals from foreign companies, including BP, todevelop the Kirkuk field because the extraction of oil in these fieldsdecreased recently.

Iraq and BP agree production increase


ITF boosts technology development

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E x e c u t i v e s C a l e n d a r 2 0 1 2

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

AUGUST 2012

28-31 Offshore Northern Seas STAVANGER www.ons.no

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




JJIHADIST ATTACKS ON Yemen's energy sector haveincluded the ramming of a refinery complex inMa'rib and storage tankers in al-Shihr port usingfour suicide vehicle bombs in September 2006, the

June 2008 rocket attack on the Safir refinery in Ma'ribprovince, the May 2008 rocket attack on the Aden refinery,the explosion of a device near the Nexen oil company'sheadquarters, a rocket attack on a compound in San'ahousing Safer and Nexen employees in April 2008, thebombing of a liquefied natural gas (LNG) pipeline in Shabwaprovince in September 2010, and the 15 October 2011double IED against the LNG pipeline supplying the Balhafterminal, halting production at the LNG plant in which Totaland Hunt Oil hold the largest shares. Al Qaeda in theArabian Peninsula (AQAP) also has a presence in al-Rada',Bayda province, less than 70-km from the oil pipelinesupplying Ras Isa.

AQAP is very likely to respond to airstrikes against itsposition, or to military offensives against it, by mountingattacks on energy targets. However, the capture of strategicassets like the Balhaf terminal would need to be precededby a prolonged period of fighting weakening security forces.

The group has also frequently stated that foreign energy firms areplundering Muslims' oil wealth, and in August 2009 warned that even if USfirms pulled out, jihadists would attack any Russian, Chinese or European firmswho moved in to replace them. Accordingly, further attacks on energy assets inYemen are likely in the next year, even if these only target pipelines rather thanlarger complexes.

Tribesmen also attack pipelines to protest government or energy firmactivities. Attacks not claimed by AQAP are likely to be the work of tribes.Examples include the bombing of the pipeline supplying Ras Isa oil terminal on6 October 2011, opening fire at the Asad al-Kamil oilfield in Ma'rib province on25 May 2010, and a number of earlier bombings of oil pipelines in Shabwaprovince, in Maswar (southeast of San'a), and of the Ma'rib-Salif pipeline.Tribesmen are also likely to kidnap energy employees, particularly around San'aand in remote desert areas of al-Jouf, Shabwa and Hadramawt provinces. On 20January 2009, a German gas company employee was abducted in Shabwaprovince and on 19 September 2008 two Colombian gas engineers werekidnapped near Balhaf, Shabwa province. In both cases the perpetrators wereattempting to negotiate the release from prison of fellow tribesmen.

Tribesmen regularly hijack or block fuel tankers during disputes with thegovernment or energy firms. The San'a-Ma'rib road, which passes through theJahm and Nihm, Bani Matar and Bani Husheish tribal areas, is particularly proneto tribal roadblocks and hijackings; on 5 February 2010 the Jahm tribe blockedmilitary convoys and propane tankers.

On 25 February 2012, President Saleh officially handed power over to hisdeputy, Abd Rabbo Mansour Hadi. This has reduced the risk of large-scale protestsin urban areas, including San'a, Ta'iz , Aden, Hodeida and Sa'da, until at least mid-2012. However, these are likely to resume again on a smaller scale because anumber of opposition groups did not support the transition deal with formerPresident Saleh. This is the despite the fact that the main opposition group, theJMP, did reach an agreement with Saleh. These groups view the new governmentas too close to the establishment that supported Saleh, which heightens the riskthat will resume protests in San'a, Ta'iz and other cities. In San'a, protest hotspots

include the presidential palace, the state television headquarters, the Ministry ofDefence and San'a University. Protesters are not likely to specifically target foreignindividuals, companies, or hotels, but hotels hosting political or diplomaticmeetings will be at risk of collateral damage during armed confrontations.Property damage in the vicinity of protesters is likely, though this would probablybe modest as it usually results from small-arms fire.

Separately, there is a separatist movement in the southern provinces that isalso unlikely to support the new government. These separatist groups are verylikely to protest in the southern provinces of Lahj, Aden, Abyan, Shabwa andHadramawt. Protests in the south are very likely to become more violent thanfarther north and property considered to be owned by northerners is at risk ofarson, shooting and grenade attacks. On 21 February 2012, in al-Mukalla,Hadramawt province, security forces opened fire on a demonstration calling for aboycott of February 2012 presidential elections. Roadblocks on major highwaysand intersections, including access routes to ports and airports, in southernprovinces are likely.

As with the previous government, the post-Saleh Yemeni government underhis former vice president Abed Rabbo Mansour Hadi is unlikely to have themilitary capability to impose its writ on all of Yemeni territory. The al-Ahmarfamily, which leads the Hashid tribal federation, and Major General Ali Mohsenal-Ahmar, who commands the 1st Armoured Division, were key Saleh allies whoplayed a critical role in keeping him in power for 30 years. Although they havenow turned against him, they are likely to maintain their influence under Hadi,reducing the risk that contracts with oil firms would be reviewed.

Hadi's government will probably be dominated by northern tribal elites asbefore. As such, Saleh's removal is not likely to be followed by majorconcessions to the southern separatists, who would be likely to seek to declarean independent southern Yemeni state in the three-year outlook, although theycurrently do not have the military capability to do so. ■

*Exclusive Analysis Ltd is a specialist intelligence company that forecastscommercially relevant political and violent risks worldwide. For additionalinformation, www.exclusive-analysis.com

Exclusive Analysis - violent risk hotspot map

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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


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BBIG SPENDERS: THE outlook for the oil and gas industry in 2012, isthe Economist Intelligence Unit’s (EIU) second annual industrybarometer, commissioned by GL Noble Denton. The report surveyednearly 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 thebusiness outlook for their company, compared with 76 per cent last year. Just 8per cent of those polled described themselves as pessimistic over performancein 2012.

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

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

This year, the Middle East was placed in the top five, according to oil andgas executives, dropping two places since last year. North America tops the list,with the Far East (including China, Japan and Korea) placing second and South-east 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 FarEast, fourth. The Far East (including China, Japan and Korea) has emerged as thekey 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 ofpeople selecting this option rising from 42 per cent to 56 per cent. Downstreamactivities are also expected to provide a stronger source of growth than lastyear, rising from 10 per cent to 14 per cent.

New energy politicsThe report touched on the implications from a year of turmoil in the Middle Eastand North Africa (MENA). The ongoing political unrest in the MENA region willhave 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 obviousconsequence for oil companies. “As of now we have 540 security consultantsworking for Schlumberger, 440 of these in Iraq. And I suspect we will have 100in Libya by year-end,” says the chairman of Schlumberger, Andrew Gould.

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

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

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

professionals expect to see increased investment in exploration activities overthe next year, with only 4.3 per cent anticipating a decline.

The upstream remains the core focus for spending. A majority of respondentsidentify the upstream as the key area for business growth in 2012, meaning thatexploration will be a major beneficiary of increased investment. Our surveyshows that 41 per cent of industry professionals expect to see increasedinvestment in exploration activities over the year, with only 4 per centanticipating 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 newfinal investment decisions since the start of 2010 for more than 400,000 barrelsof oil equivalent per day of new production. As spending ramps up on these andother projects, it expects that overall capital spending levels will increase aswell. In general, Shell sees a robust demand outlook for oil and gas, and hostgovernments and regulators are supportive of Shell’s plans to invest for newenergy supplies. “The thinking tends to be long-term – many years or evendecades in our industry, rather than driven by short-term factors,” says Shell’schief financial officer, Simon Henry.

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

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

Source: Economist Intelligence Unit

2011:

16% 33% 33% 11% 4%

20% 43% 22% 9% 3%

2012:

(% respondents)

Invest substantiallymore (At least 25%annual increase)

Invest somewhat

more

Keep investmentthe same as before

Investsomewhat

less

Invest substantiallyless (At least 25%annual decrease)

Results showing respondents’ answers regarding capital investment

Middle East and North Africa drops down list of most promising regions

for revenue growth in 2012

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

Confidence returns

to oil and gas sector



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.

Honghua Golden Coast Equipment FZE introductionHonghua 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 8807066Fax:+009714 8807061

Website : www.hhcp.com.cnwww.hh-gltd.com

approach in the Middle East. For example, CarlSheldon, the CEO of Abu Dhabi National EnergyCompany (TAQA), sees the company spendingUS$2 billion in 2012, a small increase on theprevious year: “Essentially we have a capitalspending programme that started in 2010 andgoes up to 2013.”

The overall message from the report is that forthose plays where the economics are supportive, oilcompanies will continue to spend big in 2012.There remains a big caveat, however: if globaleconomic conditions were to worsen, oil and gascompanies, whether big or small, would have toscale back their spending commitments in thoseareas where they can do so without creatingdamage to their wider portfolio.

“While capital expenditure looks set to take off,industry leaders will need to invest selectively thisyear, keeping operating risks low during a period ofprolonged uncertainty. Their success will be definedby an ability to develop innovative approaches tooperating more safely, efficiently and sustainablythan ever,” said Paasivaara.

HurdlesDespite the more buoyant outlook for the oil andgas sector in 2012 if global economic conditions dodeteriorate, oil and gas companies will have toscale back their spending commitments where they

can do so without creating damage to their widerportfolios, said the report.

Paasivaara added: “Findings from the reporthighlight a wealth of barriers to success, from risingoperating costs to the worry of an impendingshortage of skilled professionals and an uncertainregulatory environment in the post-Macondo era.”

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

that they expect an increase in wages over the next12 months. The second-biggest concern is therising cost of contractors, with 54 per centexpecting costs to increase, compared with only 11per cent anticipating a decline.

According to the EIU report, skills shortages arebecoming more and more acute and this issuecomes out of the survey as one of the majorobstacles to growth over the next 12 months. Lastyear, skills issues came fifth on the list ofbarriers and were only identified as a top threeissue by 25 per cent of respondents. This year,the issue has risen to second on the list, andhas been identified as a key barrier by 34 percent of respondents. n

Download the full report at: www.gl-nobledenton.com


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Which sgment of the industry do you expect to see the strongest business growth in the next 12 months?Select one. (% respondents)

Upstream

Source: Economist Intelligence Unit

Midstream Downstream Marketing Upstream Midstream Downstream Marketing

2011:

42% 22%10%17%

2012:

56% 8%14%12%

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

A majority of respondentsidentify the upstream as thekey area for business growth

in 2012


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

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HERITAGE OIL REPORTED that drilling of the Miran East-1 explorationwell in the Kurdistan region of Iraq has commenced with an estimatedtarget depth of approximately 4,000 meters. This is the first well to bedrilled on what the firm described as a highly prospective easternstructure, which has an area of approximately 130 sq-km.The well is targeting exploration potential within the Cretaceous andJurassic reservoir intervals of the eastern structure, contiguous withthe hydrocarbon bearing Miran West structure. The well design utilises recently acquired 3D seismic data and theenhanced understanding of the structural configuration within theMiran Field that this has provided.Drilling of Miran East-1 is expected to take approximately sevenmonths with multiple intervals to be evaluated and tested as the wellis drilled."Our work program in Kurdistan continues with the spudding of theMiran East-1 exploration well. The large, undrilled Miran East structurehas the potential to add significant hydrocarbon resources at all of themultiple reservoir intervals," said Heritage Chief Executive Officer TonyBuckingham.The Miran Block has an area of 1,015 sq-km and is located west of thecity of Suleimaniah. The Miran Block contains two large structures,Miran West and Miran East, which have been mapped from 2D and 3Dseismic programs conducted by Heritage.Heritage Energy Middle East, a wholly-owned subsidiary of Heritage, isthe operator and holds a 75-per cent interest in the Miran Block andGenel Energy the remaining 25 per cent, although there are also thirdparty back-in rights.

A SUBSIDIARY OF Honghua Holding of Chinahas awarded Aker Solutions a contract todeliver high specification drilling equipmentcomponents for seven new onshore drillingrigs in the Middle East region.

The contract is valued at US$64mn.Honghua is building a series of sevendrilling rigs for a premier drilling companyin the Middle East region. The contractincludes options for another four identicaldeliveries.

Aker Solutions will deliver the firstequipment sets to the customer in thefourth quarter of 2012. All equipmentdeliveries will be completed by the summerof 2013.

Each drilling equipment deliveryincludes a drawwork, three mud pumps, a1,000 tonnes top drive and other equipmentfrom Aker Solutions. The majority of theequipment will be delivered from AkerSolutions' subsidiary in Erkelenz, Germany."This contract underlines the quality of Aker Solutions' drilling equipmentportfolio, combined with our proven execution ability on multi-rig projects andthat our drilling expertise and high specification equipment can be applied inthe onshore drilling market," says Thor Arne Håverstad, executive vicepresident and head of drilling technologies in Aker Solutions.

Aker Solutions wins drilling equipment deal


Heritage Oil spuds Miran East well

One of Aker Solutions top drives

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TOTAL HAS ACQUIRED 40 per cent interest in the exploration licensefrom Oil Search, which is subject to the approval of Yemen's Ministryof Oil and Mineral Resources. The license covers an area of 2,954 sq-km in the eastern section ofthe Marib Basin.Total's partners will be theAustrian OMV, the CzechMND and state-ownedYemen General Corporationfor Oil and Gas (YGC). Oncethe transaction has beencompleted, the joint-venturewill resume exploration witha seismic survey whichcould be followed by adrilling of an exploration well.Arnaud Breuillac, Senior Vice-President Middle East, Exploration &Production Total, commented today: "With this acquisition, Total ispursuing its strategy of expanding its exploration and productionactivities in Yemen, in high-potential geological basins that offer aclose fit with existing projects".Total's local production in Yemen has grown to 86,000 barrels of oilequivalent per day in 2011. The Group holds producing assets in thecountry's two main oil basins, as operator of East Shabwa Block 10 inthe Masila Basin with a 28.57 per cent interest and as a partner with a15 per cent stake in Jannah Block 5 in the Marib Basin.In addition, Total participates in onshore exploration licensesthrough a 40 per cent interest in Blocks 69 and 71, and throughoperatorship of Blocks 70 and 72 with an interest of 50.1 per centand 36 per cent respectively.

Detailed map of Yemen's oil blocks

GAZPROM NEFT ANNOUNCED that it had reactivated its third well, Bd1, at the Badrafield 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 saidthat “work will make it possible to determine the technical state of the well andsubsequently test four productive strata at the site.”

Well Bd 1 is 5,000 meters deep. This is the third well at Badra that GazpromNeft 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, theappraisal wells will become operational.

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

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

The international consortium working on Badra oil field comprises GazpromNeft (30 per cent), Korea’s Kogas (22.5 per cent), Petronas (15 per cent) andTPAO (7.5 per cent). The Iraqi Government, represented by the Iraqi OilExploration Company (OEC) retains 25 per cent.

The Badra development project is expected to last for 20 years with a five-year extension option. The calculated investment is expected to amount toabout US$2 billion. Under the agreement, investors will be reimbursed for costsincurred 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. Firstproduction at the deposit is planned for 2013. By 2017 production is expected toreach 170,000 bpd (about 8.5 million tonnes per year) and maintain at this levelfor seven years. In total 17 operational and five injection wells will be drilled.

Third Badra well reactivated by Gazprom Neft

Total acquires exploration license forYemen operations



BAKER HUGHES HAS joined BPand Schlumberger on separatetalks with Iraq to more thandouble output from thecountry's giant Kirkuk oil fieldin northern Iraq.

"Baker Hughes, BP andSchlumberger have showninterest to develop Kirkuk oilfields," an Iraqi oil industryfigure, who is familiar with theKirkuk oil field, was reportedby Dow Jones Newswires assaying. "Iraq is conductingpreliminary talks with thesethree companies to examineplans 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 raiseoutput from the field to 600,000 bpd from 280,000 bpd currently, the sourceadded.

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

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

OIL PRODUCTION IN Iran dropped to a new low in February with crudeoutput falling by 50,000 bpd to 3.38mn bpd, according to the InternationalEnergy Agency (IEA).Western sanctions against Iran’s nuclear programme are really starting tobite and Iran’s hydrocarbon industry has already been suffering from yearsof underinvestment.The IEA data for February revealed that Iran posted its lowest output levelsince late 2002. Late last year, the IEA forecast that Iranian productioncapacity would decline by 890,000 bpd to just under 3mn bpd by 2016 as aresult of tighter sanctions.Iranian Oil Minister Rostam Qasemi countered that the IEA's figures andestimates were incorrect and that neither production levels nor exports havefallen. Speaking in Kuwait recently, where he was attending theInternational Energy Forum, Qasemi stated that Iran is "exporting what weare supposed to within OPEC."There is the distinct possibility that Iranian output could fall even furtherthis year. In its monthly market report, the IEA said that from July onwards -when a European Union (EU) oil embargo comes into effect - Iranian exportscould be cut by around 800,000 bpd to 1mn bpd, about a third of thecurrent total."Iran will be casting around trying to find buyers for 800,000 to 1 millionbarrels," said David Fyfe, head of the IEA's market and industry division,adding that potential reductions in oil exports "could be much biggerthan that." The IEA based its figures on the 500,000-600,000 bpd of oil Iran exported tothe EU before sanctions hit and the assumption that its other buyers wouldalso scale back volumes in order to avoid breaching the sanctions.

Iran’s oil output drops to a new low

24

Map of Iraq’s main oilfields

Firms in Kirkuk oilfield upgrade talks

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26

KOREA NATIONAL OIL Corporation (KNOC) has signed a contract todevelop three undeveloped oil blocks in Abu Dhabi with the AbuDhabi National Oil Company (ADNOC).Under the contract Koreawill take a 40 per centinterest in the fields(KNOC 34 per cent, GSEnergy 6 per cent), withthe remaining 60 percent being held byADNOC. The contract covers threeundeveloped oil blocks,two onshore and one offshore, which have high explorationpotential, the company said in a statement.The combined oil initially in place for the blocks stands at 570mnbarrels. The area covered by the blocks is 11,560km², one tenth ofthe Abu Dhabi area. Development work will commence immediately with productionexpected to begin in the coming years. Oil production is expected tobegin in 2014, if the development starts as planned later thismonth, and could rise to 43,000 bpdCommenting on the announcement, Hong Suk Woo, Minister of theDepartment of Knowledge Economy, said: “The contract betweenthe governments of Korea and UAE are in three highly prospectiveareas and will allow Korea to secure up to an additional 570mnbarrels of discovered petroleum initially in place."This contract further strengthens the important relationship betweenboth governments following last year's MoU for co-operation in theoil & gas sector.

PH PETRO HAS completed the single-well test project for Oman’s DaleelPetroleum Company which has delivered an impressive 134 per centincremental oil gain. The project marks the debut of SUR+ (Surfactant Plus) in the Middle Eastand PH Petro’s first foray into the region. PH Petro undertakes EORprojects in South East Asia from concept to completion and SUR+ hasbeen field tested in more than 18 fields and 50 wells in various producingformation.The recently completed project gauges the effectiveness of PH Petro’ssurfactant technology in improving oil recovery at a Daleel producer well.PH Petro’s SUR+ technology delivered 5,785 barrels of cumulative oilexceeding baseline forecast by 3,171 barrels of oil. Due to the favorableresult, evaluation efforts are now underway to extend the EOR pilotflooding to cover several injectors and a few more IOR (improved oilrecovery) at producer wells. The field implementation is forecasted todeliver incremental gain of between 100 to 300 per cent. “Our test for Daleel has proven that our technology can increase oilrecovery at a reasonable cost and in a very practical manner. This is astrong start to our Middle Eastern operations and we look forward tobecoming 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 confidenceand support and anticipate a very productive partnership ahead,” saidFairuzz Nasron, President and Group CEO, PH Petro.Daleel Petroleum Company LLC is a 50/50 joint venture betweenMazoon Petrogas SAOC and Mazoon Petrogas BVI. It explores, appraisesand processes hydrocarbon reserves in Oman’s Block 5 onshore fieldsouthwest of Muscat.

SEADRILL HAS SIGNED a US$184mn contract with Saudi Aramco for theemployment of its jack-up rig West Callisto offshore Saudi Arabia, a companystatement said.

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

The potential revenue for thethree-year period is approximatelyUS$164 mn plus a US$20mnmobilisation fee to cover variousupgrades, dry tow vesselexpenses and dayrate in themobilisation period.

Alf Thorkildsen, CEO inSeadrill Management AS,commented: “We are delighted tohave signed our first contract withSaudi Aramco for operation inSaudi Arabia. This awardcomplements 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 toimprove our earnings visibility for this asset class going forward."

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

Seadrill agrees jack-up rig deal in Saudi

One of the contracts is foran offshore block

GULF KEYSTONE PROVIDED an update on its ongoing exploration andappraisal program in the Shaikan block in Kurdistan Region of Iraq.The Shaikan block is a major discovery with independently auditedgross oil-in-place volumes of between 8 billion barrels to 13.4 billionbarrels calculated on the P90 to P10 basis, with a mean value of 10.5billion barrels.The well testing program for the Shaikan-4 appraisal well remainsongoing, 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 faraggregate flow rates in excess of 14,000 barrels of oil equivalent perday ("boepd") have been achieved. Portions of the well that appear tobe high quality oil reservoir on the electric logs, and where provencommercial flow rates were achieved by testing previous wells, willnot be tested. The first five tests have been conducted in the northern"footwall" - on the lower side of the inclined fault bounding theShaikan structure. This is the first occurrence of flow from thefootwall and proves an extension of the Triassic and Jurassicreservoirs outside the central part of the structure. The latest test(Test 6) is being conducted in the "hanging wall" (the upper side ofthe inclined fault) from a new reservoir in the uppermost Sargeluformation which had not been previously flow tested. The test isongoing and rates in excess of 4,000 boepd have been recorded.After drilling the Shaikan-5 appraisal well to the depth of 1,876meters in the Jurassic, it became necessary to drill a sidetrack due toa portion of the drill string becoming stuck in the hole. The sidetrackoperations were successfully performed at the depth of 1,370 meters,after which the Shaikan-5 drilling operations have resumed below1,730 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 thedepth of 2,058 meters in the Jurassic. The well will drill to theestimated TD of 3,800 meters subject to technical conditions.


PH Petro completes EOR project in Oman

Gulf Keystone reveals Shaikan block resultsKNOC agrees further contracts with ADNOC

The jack-up rigWest Callisto

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IRAQ AND A CONSORTIUM led by Russia's state oil producer GazpromNeft has awarded Petrofac a US$329.7mn deal to develop the untappedBadra 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 saidPetrofac would builda central processingfacility for oilproduction in thefield but he providedno further details,reported Dow Jones.The consortium-alsoincludes Korea GasC o r p . ( K o g a s ) ,Turkish PetroleumCorp., or TPAO, andMalaysia's Petronas,is planning to startfirst production from the field by mid-2013, Gazprom Neft executiveshad said.Gazprom Neft-operated consortium has started last year drilling in the fieldwith estimated proven reserves of 3 billion barrels. It plans to drill some 11wells in the fields in three years. Gazprom, which holds the largest stake inthe consortium at 40 per cent, would receive along with its partners apayment of US$5.50 for each barrel extracted from the field as soon as thefield reaches output of 15,000 barrels a day by mid-2013.

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

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

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

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

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

Boushkan oil field is located 100 km north of Bushehr and 30 km fromDalan gas field. The field's in-place reserves have been estimated at about340mn barrels with a single well drilled in 1963.

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

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

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

Ukraine to invest in three Iranian oil fields

28

The Badra oil field remains untapped so far

Petrofac awarded Badra oil field deal in Iraq

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

MMUBADALA DEVELOPMENT CO. is working on a project thatwould use floating LNG storage and a regasification unit, thecompany said in a statement. The first supplies are expected inthe next two to three years, it said.

Iran threatened earlier this year to close the Strait in response to sanctionsthat the US and Europe are imposing because of the Islamic republic's nuclearprogramme.

Offshore facilities"The project would be outside the Strait, so that would give more supplysecurity 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 thegovernment, will also work on setting up the plant.

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

www.mubadala.ae

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 throughthe Strait of Hormuz.

Mubadala plans floating LNG terminal

in Fujairah CASTROL ULTIM

AX CRITICAL PERFORMANCE


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

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

Industrial expansionThe UAE already imports gas from Qatar through the Dolphin Gas pipeline, aventure with Total and Occidental Petroleum Corp. The pipeline operates atabout two-thirds of capacity because the UAE has been unable to buy additionalfuel from Qatar, which has committed its supplies to other buyers.

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

Dolphin Energy Ltd., 51 per cent-owned by Mubadala, pumps about twobillion 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 situatedoutside the Strait of Hormuz which has been the centre of attention over the lastfew months with Iran repeatedly threatening to close the major oil supply route.

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

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

Ipic, established in 1984, is a wholly-owned Government of Abu Dhabicompany with a focus on investments in international energy and energy-related industries and strategic projects on behalf of the Government of AbuDhabi. Ipic currently holds more than 15 investments and projects on fivecontinents. ■

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

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

Bahrain's gas import plans have long been hampered by political tensionwith regional producers Qatar and Iran and a looming gas shortage threatensthe country's growth.

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

JORDANIAN AND IRAQI energy officials have entered advanced talks over anatural gas deal that would provide the Kingdom with an alternative energysource within five years.

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

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

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

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

In addition to Iraqi gas, Amman is exploring the possibility of importingQatari liquid gas, to be stored aboard a ship in the Port of Aqaba ahead ofthe 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 toimplement a nine per cent increase in electricity rates last month, but thegovernment suspended the decision amidst a popular backlash.

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

Jordan and Iraq near agreement

32

www.gazprom.com


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METERING SYSTEMS FOR oil and gas are becoming increasinglyimportant. As prices for petrol and natural gas have increaseddramatically in the last ten years in Romania, companies such asSyscom 18 have seen an opportunity and started to engineer andmanufacture metering systems for oil & gas companies. Most of theunderground natural gas storage facilities in the country aremeasured by fiscal metering stations manufactured by Syscom 18.These stations (bi-directional, using ultrasonic flow meters andturbines for verification, GCs for calorific power calculation) measurethe natural gas accurately during the injection or extraction phase.Quality metrological services have helped Syscom 18 win orders fornatural gas metering stations on behalf of Romgaz, Transgaz and

Petrom, all large national oil and gas companies. Six years ago, newlegislation in Romania meant tank farms had to install fiscal meteringskids for all refined products. “That was a good opportunity for Syscom 18 who became thelargest Romanian manufacturer, having more than 200 skidsinstalled in Romania, Iran, Kazakhstan, Libya and Jordan. Eithermass or volume based, Syscom 18 has manufactured skids for allkinds of oil products, for trucks, wagons or pipelines. Syscom 18was also the first Romanian company to receive MID (MeasurementInstruments Directive) approval and we have invested in a newcalibration facility in order to do complete tests and verifications inour own factory,” Mr. Ion Andronache, CEO of Syscom 18, explained.

34

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

Metering systems on the market

Gas


Oil Well Cement (OWC) produced by Oman Cement Company (S.A.O.G) under accurate temperatures is an obvious choice for oil well cementing worldwide and now it is ready to face the challenges of highly specialized arctic and horizontal cementing:

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• Easy to disperse resulting in considerable cost savings

• Used by major oilfield companies such as: Petroleum Development of Oman (PDO), Schlumberger, Halliburton & Occidental

• Exported to GC Countries, Iraq, Yemen, Libya, Sudan, Tanzania, Turkmenistan, Pakistan, India and Syria.

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

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


TTHE NEW REPORT* found that the MiddleEast is now facing a natural gas scarcitydue to increasing demand and inefficientutilisation of subsidized natural gas by

the energy intensive industries, which has led tothe restriction of supplies and posed a subsequentthreat to the global petrochemical market.

Huge natural gas resources and cheaperfeedstock availability turned the Middle East intothe hub of the global petrochemical industry overthe last decade by making the region the mostcompetitive in the world. Middle Easternpetrochemical producers use natural gas as a keyfeedstock due to the availability of subsidies. Thismeans that natural gas in Middle Eastern countriescan be as much as 60-70 per cent cheaper thannatural gas found in Europe and North America.

ScarcityHowever, the subsidies on natural gas productionoffered by countries such as Saudi Arabia, Iran andQatar have led to the inefficient utilization of theavailable resources, leading to a decline in thesupply of ethane feedstock. Feedstock costsdetermine 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 thepetrochemical producers significantly.

In addition, the Organization of PetroleumExporting Countries (OPEC) quota limits crude oilproduction, thereby also limiting associated naturalgas production. Despite all Gulf countries producingmore than their allotted quota, production isinsufficient to meet burgeoning demand from thepower, transportation and petrochemical sectors.

Saudi Aramco, the sole supplier of ethane inSaudi Arabia, stopped allocating ethane to newpetrochemical projects in 2006, and pre-existingsupply agreements have not received theirallocated limits since 2009.

Lack of development of Iranian non-associatedgas reserves has also led to the scarcity in ethanesupplies, and Qatar have imposed a moratorium

upon further development of gas reserves, in orderto assess sustainable rates of gas production,halting allocation of the country's gas for industrialprojects until 2014. ■

*Petrochemical Industry - Key GeographiesExperiencing Change in Feedstock ScenarioThe study provides an in-depth analysis of thepetrochemical feedstock supply scenario in keylocations, while explaining the reasons for adecrease in the supply of ethane feedstock ingeographies such as the Middle East and Canada. Italso explains the impact of new oil and gasdiscoveries on the petrochemicals industries incountries such as the US, Brazil and Canada. Thestudy provides the basic petrochemicals (ethylene,propylene, butadiene, benzene, toluene, xylenesand methanol) capacity split by feedstock for all thefive regions. The report highlights the change in thesupply trend of petrochemical feedstock sourcessuch as natural gas and crude oil. The report is builtusing data and information sourced from proprietarydatabases, primary and secondary research and in-house analysis by GlobalData's research team ofindustry experts.

Feedstock costs determine the success ofpetrochemicals producers

Subsidies have led to theinefficient utilization of the

available resources

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Securing natural gas feedstock in the Middle East has becomeincreasingly difficult in the last few years, threatening the region'sdominance as the most economical petrochemicals producer,according to a new report by business intelligence companyGlobalData.

Feedstock shortage threatens regional

producers

GRAHAM CORPORATION, A designer andmanufacturer of critical equipment for the oilrefining, petrochemical and power industries,including the supply of components and rawmaterials to nuclear energy facilities, recentlyannounced that it has secured US$8mn in ordersthat are expected to be delivered in Q4 ofGraham's fiscal year 2013, which ends March 31,2013.

The steam surface condensers for the China-based project will be used in a plant that produces

petroleum products from coal. As the world's largestproducer and consumer of coal, China hasembraced CTL technology. The petrochemicalproject in the Middle East is for an ethylene facility.Petrochemical projects have been advancing withthe gradual improvement in the global economy. Allfive steam surface condensers will be built inGraham's Batavia facility.

James R. Lines, Graham's President and ChiefExecutive Officer, commented, "Our bidding activityhas 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, itis very encouraging to have these projects, whichhave been in our pipeline for over a year, finallycome to fruition.

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

Graham Corp secures US$8mn orders



38

TOTAL SIGNED A Memorandum of Understanding (MoU) with KuwaitPetroleum International (KPI) and Petrochemicals Industries Company(PIC) to take a stake in the Zhanjiang refinery project in China.Both companies are whollyowned subsidiaries of KuwaitPetroleum Corporation (KPC)and KPI, PIC and Total haveagreed to form a consortium,which will potentially holdinterests in two joint-ventures together withSinopec.The MoU revolved aroundparticipating in thedevelopment of the 300,000 bpd full-conversion refinery integratedwith petrochemicals and marketing, in partnership with Sinopec, Totalsaid in a statement. The proposed refining and petrochemicalsplatform will be designed to process Kuwaiti crude as feedstock and toproduce high-quality refined and petrochemicals products.“KPC is pleased to expand its cooperation with Total” declared MrFarouk Al Zanki, KPC Chief Executive Officer, after the signing of theMoU. “Total and KPC’s strategic objectives in Guangdong are highlyaligned,” he added.

THE SAUDI BASIC Industries Corporation(Sabic) has signed a TDI (toluenediisocyanate) and MDI (methylene diphenyldiisocyanate) technology license agreementwith Mitsui Chemicals.

Under the agreement, Mitsui will providemanufacturing technology for producing TDIand MDI, which are both raw materials forproducing polyurethane. The agreement alsoprovides for joint technology development inTDI/MDI, the company said.

The agreement was signed by Mohamed Al-Mady, Sabic vice chairman and CEO, andToshikazu Tanaka, Mitsui Chemicals president

and CEO, at Sabic’s headquarters in Riyadh.Al-Mady said the agreement will spearhead

a strategic collaboration between the twocompanies to explore future possibilities tocollaborate in the polyurethane (PU) business.

“The agreement will spur our strategicbusiness plan to penetrate the globalpolyurethane market as well as power theambition and competitive advantage of ourcustomers for the long term,” he said. “It willalso enable a fast development of PUapplication industries in Saudi Arabia,especially with regards to thermal insulationwhich will contribute to employment creation.”

“Through this technology licenseagreement, we will strengthen our productcapabilities with high quality TDI and MDI andexpand into the polyurethane business,” Al-Mady added.

Tanaka commented: “For Mitsui Chemicals,this license agreement will be the largest andmost extensive one we have ever made. Wewill support this project full force on every frontand are committed to its success. I hope that itwill be just the first step in a future businesspartnership with Sabic, which may includeestablishment of a strategic supply base forcompetitive TDI/MDI.”

QATAR PETROCHEMICAL COMPANY (QAPCO) has awarded Taiwanese companyCTCI a US$165.9mn contract for the first phase revamp of its main ethyleneproduction facility in Mesaieed Industrial City.

The contract value could rise in the future through additional optionalrequirements costing US$48.3mn making the total investment cost for Phase 1come 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 VicePresident for Plant Engineering Operations Mr. Nitta Masami.

Phase 1 will see the installation of new furnaces and ethylene storagetanks. The project will utilise the latest technology in combustion, wastecontrol and on-line monitoring. The main benefits would be direct andsignificant reduction in Nitrogen Oxides (NOx) emissions to the air, reuse ofCoke inside the furnaces which will prevent soil and air contamination, betterefficiency in fuel consumption and improved yield which will improveproductivity and as a consequence reduce harmful waste, officials said. PhaseII of the project, which is estimated to cost US$550mn, looks at increasing the

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

Qapco awards contracts for ethylene plant

The number of refineries in China is growing

IAIN JOHN LO, Vice President New Business Development &Ventures, Shell Chemicals spoke to Oil Review about ShellChemical’s strategy in the region and what the company’s keymarkets are.Lo emphasised that Shell Chemicals does not want to get involvedin everything as they want to remain focused on their own portfolio. “We are a global business and we have a few derivatives which webelieve are leading the market: including propylene oxide and Alphaolefins. We consider these as strong products," added Lo.Lo believes there is a general slowdown in feedstock demand due tothe economic downturn, but claimed that Shell takes a long termview when working on large scale projects. “Fundamentally theoutlook 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 IndustriesCorporation (SABIC), and since 1984 working on SADAF (Saudi ArabiaPetrochemical Company) which is a long term project. Lo talked aboutthe importance of cluster cities, like Jubail in Saudi and Ras Laffan inQatar 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 isessentially gathering associated gas. But importantly withinassociated gas there is interesting feedstock. Clearly we areinterested in building some synergies with petrochemicals.”


Sabic agrees technology deal with Mitsui

Shell puts emphasis on integration Total and KPC agree China refinery deal

The signing ceremony for the Phase 1 contract

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DONALD C CLARK, VP, Global IndustrySolutions, Invensys Operations Managementspoke to Oil Review about the value solutionshis division brings to the upstream anddownstream sector in the region.Clark’s remit covers five heavy processingindustries that include upstream oil and gas,chemicals, mining and power (fossil andnuclear). The team provides business strategiesin the core global industrial markets. Clark explained that Invensys will knit togethersolutions across their portfolio to deliver value.He cited the example of the company’s work onbrown fields in the region. The mature market isa one of the company’s focus and one particularplay, even in this market, is brown fields whichsee Invensys taking existing assets andrevitalising them. A great example of this isInvensys work on a 20 plus-year-old platformoff Abu Dhabi. “We are helping modernisethese platforms by improving their safetyapplications, improve their productivity. So weare upgrading the technology information ofthese platforms. With upgraded informationservices we can bring in optimised schedulingand we can effectively revitalise these

platforms,” he added.In the downstream sector Invensys haveprovided three unique systems for refineryoperations that are new to the market. Onesolution which has proved very popular is theenergy management system. In a refinery youneed a good balance of energy sinks andsources and to make sure it does not get out ofsync which can lead to unscheduled shut downs.“That is why we have solutions that look at theconsuming and producing aspects in refineryand maintain the balance. The energymanagement solution comprises every piece ofour portfolio, from sensors, informationinterface to data logging.”“The other solution we are very excited aboutis refining optimisation. We are takingsoftware programmes that essentially modelthe kinetic process going on in a crude unit, ina cracker and we are looking at the marketprice of the finished product. We run theseprogrammes on a periodic basis and givesguidance to how you should optimally in termsof profitability set the parameters for therefinery. It is called Romeo.”

The third solution that Invensys is on the vergeof introducing is based on our Triconex system.It is a safety shutdown system and according toClark it is a market leader. It is triply redundantwhich is unique. He provided the example ofSaudi Aramco’s Ras Tanura which uses thissystem. It can provide analyses of each unit ina refinery and give a quantitative measurementof how safe they are operating. With this youcan push certain units to operate at a highconversion rate because you know you are stillsafe. So you arrive at a real time assessment ofthe degree of safeness.Clark concluded by talking about Invensys NetOil and Wet Gas modeling-based system thatmeasures the multiple phases and multiplecomponents, liquids and vapors like water, oiland gas, in the same stream. This system isbeing used successfully in Algeria with state oilcompany Sonatrach. Due to the nature of thenatural gas liquids in Algeria’s wells there is aneed for a separator on top of most wells in thecountry. With the Wet Gas application there isno need to separate the gas and liquid on siteand it can all be pumped to a central placewithout separation first.

39

Invensys’ value proposition

Petro

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OOMAN’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 vastbulk of the country’s oil and gas production, though other foreign producers arealso making a material contribution.

And what a job PDO has done in recent years by turning around Oman’sdwindling production volumes, to restore output to former levels and pocketprecious more income for the government as it continues to expand and diversifythe 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 continues to invest in the latest technology to helpdevelop its meagre resources

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

PDO delivers again with oil and gas

production boost

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PDO’s widespread use of wide azimuth 3D data collection

reflects a policy of using the most modern technology as it becomes

commercially available

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

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

Average gas production also increased by some4.4 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 rewardedtoo with higher oil market prices, averagingUS$102.90 (Dh377) per barrel in 2011, up more34 per cent from US$76.60 a barrel the previousyear.

The production trend is up even though PDO’sown oil contribution slipped marginally, the resultof labour unrest last year, among other factors.

The boost nets the government vital extrafunds for economic development, at a time whenthere is added pressure across the region for socialchange and political reform.

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

PDO’s managing director Raoul Restucciattributed the slip to lost work days throughvarious factors including rain and labourstoppages, at the time of the so-called Arab Springlast year.

That said, combined oil, gas and condensateproduction in 2011 still reached its second highestlevel on record, at 1,206,000 barrels oil equivalentper day (boepd), underlining the continuedstrength of PDO’s production drive.

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

Daily condensate production in 2011 stood at93,600 bpd, while non-associated and associatedgas production reached 463,000 and 85,000barrels of oil equivalent (boe) respectively.

Restucci said the numbers remain consistentwith PDO’s long-term oil production targets of540,000-560,000 bpd, coupled with broad plans toexpand gas output.

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

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

Considering this number is less than half thatof Kuwait (1.8 tcm), Oman’s gas exports -throughthe Oman LNG project - and production stand outas highly impressive.

The BP figures also chart the steady revival ofOman’s upstream production sector, spearheadedby 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 - butconsistently up since the government tookdecisive action to stem the material declinewitnessed early last decade.

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

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

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

This includes a successful 2011 in terms ofexploration and reservoir development with anumber of new potentially significant oil and gasopportunities and additions to reserves.

“While continuing to make conventionaldiscoveries, our exploration emphasis in 2011 shiftedto unconventional plays,” he said, highlighting theemergence of unconventional tight oil and basin-centred gas opportunities.

The increased complexity of upstream operations,and a reliance on new technology through fielddevelopment and recovery optimisation studiesadded 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 takeon more significance going forward, he reckons.

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

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

Technology driveAs part of this effort, PDO continues to invest in itsscience and technology base.

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

PDO started 3D seismic data acquisition usingspecial seismic teams working round-the-clock insouth Oman in early 2010.

Since then, it has acquired data covering over7,500 sq-km, and during this year, will launch a majornew seismic acquisition drive in north Oman’s al-Huwaisa/Yibal area covering an area of 7,500 sq-km.

PDO’s widespread use of wide azimuth 3D datacollection reflects a policy of using the most moderntechnology as it becomes commercially available.

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

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

This technology was originally developed inChina and is on trial by PDO in the Marmul area, thefirst time this technology is being used in the MiddleEast.

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

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

The technique is based on lowering a number ofgeophones into an observation well to record micro-seismic events.

In effect, the technology listens to energyemissions that result when reservoir rock cracks, anatural process known as fracking.

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

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

The trial was conducted in some extremeconditions, namely a 5,000 metre deep reservoir witha downhole temperature of around 175˚C.

Results are currently being evaluated and asecond test will take place in 2012 at the KhuludField.

EOR leadershipPDO has also carved out a name for itself in the areaof enhanced oil recovery (EOR).

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

Maintaining the life of each field and ensuringmaximum recovery is one of PDO’s strategicpriorities.

In effect, each oilfield has to be individuallynurtured by petroleum engineers with tailor-madestrategies.

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

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

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


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


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Oman targets gas sector boost

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

In such capital-intensive projects, PDO carriesout intensive studies to ensure the right technologyis chosen to maximise production flow from eachfield.

In many cases, small-scale field trials are carriedout to make sure the chosen technology works inpractice.

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

The field, with an estimated 2.4 billion barrels ofoil, was originally discovered in 1982, but the heavynature of the crude means it has so far beenimpossible to produce.

PDO engineers are now busy trying to identifyenhanced recovery solutions to unlock the oil fromthe field.

Amin development One example where engineers are already making abig difference is the Amin field, PDO’s seventhlargest oilfield, with 1.2 billion barrels of oil inplace.

Even though just 13 per cent of the oil has beenproduced, output has been falling, meaning there isplenty of potential for increased recovery if the righttechnology can be adopted.

Studies suggest that capital-intensive EORtechnologies such as steam or polymer injectionmight not necessarily provide the best solution orvalue for money.

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

order to maintain pressure and enable wells tocontinue producing at stable rates over the next fewyears.

The Amin Infill and Water Injection Projectinvolves the drilling of 118 horizontal producingwells and a further 35 vertical injection wells thatwill pump up to 70,000 cubic metres a day of waterdeep underground to help sustain oil production.

Water injection provides a cost-effectivesolution and gives PDO time to continue studyingEOR that could be implemented in the years tocome.

New projectsKeeping busy is how PDO has managed to maintainand improve its production profile steadily throughrecent years and this means consistently deliveringon new projects.

“In fact, we need to bring on-stream at leastone major new project a year if we are to continueachieving our long-term oil production target of540,000 to 560,000 barrels per day,” said Restucci.

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

Late in 2011, PDO achieved first production andfirst steam at the Qarn Alam steam project, anothermajor EOR project.

Some 2,700 tons of steam is now being pumpedinto underground reservoirs at Qarn Alam, whichwill help release much of the heavy crude oil fromthe field.

Production will increase incrementally overtime, and thanks to the steam injection, the fieldwill reach a production plateau of 40,000 bpd ofcrude oil in 2015/2016.

The Harweel challengeIn south Oman, PDO also continues to work towardsthe completion of what is probably its mostcomplex and technologically ambitious project everundertaken, the Harweel miscible gas project.

More akin to a chemical plant than aconventional oil facility, the Harweel plant wascompleted last year but pre-commissioning testsrevealed anomalies in some critical equipment.

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

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

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

The project’s control room has already beencompleted and key equipment such as the steamgenerator and water treatment plant are already on-site.

These are all highly demanding and complexinitiatives but PDO’s upstream engineers are risingto the challenge. ■


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In many cases, small-scalefield trials are carried out to make sure the

chosen technologyworks in practice

A KEY FOCUS for Oman right now is thedevelopment of its natural gas sector.

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

In the past decade or so, non associated gasproduction has shot up from next to nothing toclosely trailing crude oil production, the nation’sbiggest export earner.

PDO’s own gas directorate certainly had a busy2011 delivering new projects.

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

Site construction activities have already startedand design contracts awarded.

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

The project will comprise a single train in theLekhwair gas plant for exporting gas to theGovernment Gas Plant in Yibal, while condensatewill be delivered to the existing Lekhwairproduction station.

And as in the oil sector, work also includedbreathing new life into some of the nation’s ageinggas 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 powerfulcompressors to boost the recovery of gas fromunderground reservoirs.

There are two major upstream depletioncompression projects currently underway.

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

The second, at Saih Nihayda, is also wellunderway with major equipment already orderedand construction advancing ahead of schedule.

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

PDO’S ROLE AS the sultanate’s largest company and national championmeans it has a special responsibility to support employment anddevelopment opportunities for local Omanis. During 2011, the company created close to 4,300 new jobs for localpeople while awarding 25 per cent of well engineering contracts toOmani-owned enterprises. In the second half of last year, PDO developed the blueprint for a new‘In-Country Value’ strategy, aimed at supporting local communitycompanies, increasing the procurement of local goods and services, andimproving domestic capacity and capabilities.

Key targets include: Doubling the number of skilled Omanis employedby the contracting community from the current 15 per cent to 30 percent by Q3 2013.Increasing the spending on in-country goods by US$100mn per annumwith 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 annumwith 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 takethe lead when it comes to making the nation’s energy sector work forthe benefit of the whole country and its people.

Omanisation drive



CGG VERITAS COMPLETED 20mn man hours of land seismicoperations in Oman with PDO without a lost time incident (LTI). Thecompany has a long term land acquisition crew, acquiring a verylarge high-density 3D seismic program in Oman. The crew isoperated by CGGVeritas Middle East JV Ardiseis.The crew has over 360 personnel and 130 vehicles. Field conditionsinclude high desert temperatures and challenging terrain such asdense oilfield infrastructure, rocky wadis and steep jebels. "We attribute such an impressive achievement to the commitmentshown not only by the management, of both PDO and Ardiseis, butalso by the field staff themselves," said Salim Al-Rawahi, ChiefGeophysicist, PDO.

PDO'S 2011 PRODUCTION reached the second highest level in itshistory with production levels hitting 1,206,000 barrels oilequivalent per day (boe/d)."PDO has delivered stable oil production and increased gas supplyconsistent with its short and long term objectives of providing asignificant and sustainable energy and revenue stream for thebenefit of the Omani national economy and its people," PDOManaging Director Raoul Restucci said at the company's AnnualMedia Briefing held in Muscat.Daily oil and condensate production in 2011 stood at 549,280 and93,600 barrels per day respectively and non-associated andassociated gas production at 463,000 and 85,000 barrels of oilequivalent per day respectively.PDO's exploration emphasis in 2011 shifted to unconventional plays.Raoul highlighted the emergence of unconventional tight oil andbasin centred gas opportunities. In addition, field development andrecovery optimisation studies added 266mn zbarrels of oil reservesand 1 TCF of gas reserves (for a combined 450 million boe).Raoul further added that "the extensive inventorisation and fielddevelopment work has resulted in a Reserves Replacement Ratio(RRR) of 1.26, well in excess of 2011 production, while theencouraging unconventional results are expected to underpinlonger-term production opportunities after extensive appraisal,testing and maturation work."Our work this year has laid the groundwork for sustained productionand recovery optimisation," Raoul concluded.

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A new safety milestone in Oman

No LTI on Oman land seismic project PDO production levels soared in 2011

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PDO’S LATEST ANNUAL media briefing discussedthe pivotal role that operational safety plays forthe company and how ensuring the personal andprocess safety of PDO people, contractors, andtheir assets is major challenge.“It is extremely important that our staff andcontractors work in safe conditions,” PDO stated.PDO’s safety performance in 2011 recorded nowork-related fatalities and a dramatic reduction inindustrial-related lost time incidents, with theLost Time Injury Frequency standing at 0.36. The overall severity resulting from road trafficincidents has also shown improvements – mainlydue to enforcement of PDO’s stringent drivingstandards and numerous road safety engagementsheld throughout PDO’s operations. In total, PDO and its contractors have driven morethan 429mn km without a work-related fatality.Greater implementation of the In-VehicleMonitoring System (IVMS) ensured more usefuldata was collected on the driving habits of PDO drivers. With betterdata, PDO safety teams were able to target drivers to help themimprove their safe driving skills. In addition, PDO is installing Personal Navigation Devices (PND) in its

vehicles to alert drivers of impending hazards such as sharp bendsand diversions.PDO is determined to achieve Goal Zero, meaning no harm to peopleand the environment, and will continue to roll out new initiativesthroughout 2012.

Road traffic accident frequency

PETROLEUM DEVELOPMENT OMAN(PDO) signed a major contractwith Al Haditha Oilfield ServicesCompany; one of five Super LocalCommunity Contractors (SLCCs).Al Haditha Oilfield ServicesCompany will provide flowlinereplacement services.

The contract was signed byAhmed bin Hamoud al-Dur'ei,Majlis A'Shura member;Representative of the Wilayat ofAdam and Chairman of Al HadithaOilfield Services Company's Board.It was signed from PDO by RaoulRestucci, PDO's ManagingDirector.

The value of the contract totalsUS$35mn and will last for fiveyears commencing on 1st June2012. “The value of the contractwill increase according to thescope of work al Haditha cancover,” added Restucci.

Al-Dur'ei said that thecompany will begin its works inreplacing the flowline after twomonths from now in PDO'sconcession area in the north,starting from Jibal area viaKhwair towards Fahud and QarnAlam

Restucci said that signing thecontract comes as part of our "InCountry Value" strategy, which

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

“Pioneered by PDO the ICVprogramme has now expanded toother upstream operators throughOPAL who will coordinate theindustry’s efforts under theauspices of a newly formedsteering committee: “Oil & Gas InCountry Value Committee”chaired by HE Nasser bin Khamisal Jashmi, Oil & GasUndersecretary.

The five super LCCs (four ofwhich are assigned to PDO) arepart of an efforts to develope localcommunities in PDO’s concessionarea by providing them withbusiness opportunities. Prior tothe establishment of these superLCCS the share of PDO’s businessto the local communitycontractors has been steadilyincreasing during the period 2008-2011 and exceeded $100 millionin 2011.

“These local communitycontractors have grown, withincreasing efficiency andcompetitive mindset and, in manycases, have become fully-fledgedand experienced contractorscompeting in the local market,”said Restucci.


PDO signs major contract with SLCC

PDO highlights importance of operational safety

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PDO CONTINUES TO invest in 3Dseismic acquisition using state-of-the-art technology known as wideazimuth. PDO started 3D seismicdata acquisition using special seismicteams working in south Oman inearly 2010. Since then, PDO hasacquired data covering over 7,500 sq-km, and in 2012, PDO will launch amajor new seismic acquisition drivein north Oman’s Al Huwaisa/Yibalarea covering an area of 7,500 sq-km,the company highlighted in itsannual media briefing.

PDO’s widespread use of wideazimuth 3D data collection reflects apolicy of using the most moderntechnology as and when it becomescommercially available. PDO seesitself as a regional pioneer in thedevelopment of new technology. Oneexample of early-stage technologyuptake is the use of what is calledTime Frequency ElectromagneticProfiling, the latest innovation usingelectromagnetic signals to seek outhydrocarbons in undergroundreservoirs. This technology was

originally developed in China and ison trial by PDO in the Marmul area,the first time this technology will beused in the Middle East. If successful,the technology could be utilisedacross PDO’s operations.

Another technology beingimplemented by PDO, as a premierfor this region, is a process known ashydrofrac monitoring. The techniqueis based on lowering a number ofgeophones into an observation wellto record micro-seismic events. Ineffect, the technology listens toenergy emissions that result whenreservoir rock crack, a natural processknown as fracking.

In the second half of 2011, PDOperformed the region’s first hydrofracmonitoring test in the Amin Tight GasReservoir Formation. The trial wasconducted in some extremeconditions, namely a 5,000 metredeep reservoir with a downholetemperature of around 175°C. Resultsare currently being evaluated and asecond test will take place in 2012 atthe Khulud field.

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.

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

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

EOR Habhab field trial: update

PDO HAS CONTINUED to work to ensure that it operates in anenvironmentally sustainable manner. PDO has claimed that 2011 was noexception. “We continued improving our energy efficiency in terms ofthe amount of gas used tofuel our operations,”thecompany said in itsannual media briefing.Despite the fact thatPDO’s ageing oilfields areproducing increasingamounts of waterrequiring additionalenergy for treatment anddisposal, the amount ofgas used for energy has actually fallen from around 12mn cu/m per dayin 2005 to 8.4mn cu/m per day in 2011.At Amal, where PDO is currently in the process of developing a majorsteam injection project, we have embarked on a pilot aimed at testingsolar technology to generate steam during the day.The 4-acre Solar Steam Generation Pilot that is in mobilisation phase willgenerate high-temperature, high-pressure steam using parabolictroughs housed inside agriculture-style greenhouses. The goal of thesolar EOR project at Amal is to reduce the amount of natural gas burnedfor thermal EOR, releasing gas for higher value applications, includingpower generation, desalination, industrial development and export.The Amal solar EOR facility will use concentrated thermal energy fromthe sun to produce low-cost, emission free-steam that will be feddirectly into PDO’s existing steam distribution network. It is builtspecifically to withstand the harsh environmental conditions of thedesert. Specially designed light-weight reflective mirrors are used tocapture the sun’s rays and enclosed inside a glasshouse structure toprotect the system from dirt, dust, sand, and humidity. If successful, thesolar technology could be expanded to alternative applicationsthroughout PDO’s operations.


PDO’s technology push for the future

PDO’s strong environmental commitment

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An EOR project in Oman


S11 ORME 3 2012 OGWA_Layout 1 10/04/2012 12:44 Page 49


AARRANGEMENTS ARE COMPLETE for theeighth OGWA, Omanexpo’s Oil & GasRefining & Petrochemicals Exhibition &Conference. All events take place in

the Muscat IEC from 16-18 April, with theinternational Society of Petroleum Engineer’sTechnical Conference (same dates precisely) heldalongside at the Golden Tulip Hotel.

This year’s main OGWA exhibition theme isFuelling your oil and gas markets with theConference (content details below) focussing onEnhanced Oil Recovery/Building towardssustainable growth. OGWA 2010 attracted over300 local and international companies showingan extensive range of products, services,equipment and technologies relevant to theSultanate’s expanding energy plans, such as forthe development of a large and completelyintegrated refinery and petrochemical complex inDuqm which is expected to attract furtherinvestment to the Sultanate as a whole.

Key development themes this year include

EOR techniques as a priority. The country’spremier oil and gas producer (by far) PetroleumDevelopment Oman has once again signed astrategic partnership with Omanexpo for whatpromises to be one of the largest energy eventsin the region. PDO’s team of professionals willonce again be supplying key technical input tothe associated Conference, and will be prominentby their presence at the whole event, includingnumerous social functions.

With the support of the Oil & Gas Ministryand the Chamber of Commerce & Industry as wellas leading operators such as PDO itself, OmanLNG and others a useful innovation this year willbe the organisation of a special CEO Forum thatwill bring together leading business executives,policy makers and technical experts from energycompanies worldwide, all in line with theExhibition and Conference’s interlinked mainthemes as outlined above.

The OGWA forum The OGWA forum, run by IIR Middle East, willbring forth the regions critical challenges andopportunities. These will be debated by topMiddle Eastern oil and gas industry experts andpolicy makers at the Forum which will take placefrom 15 to 16 April.

With an emphasis on overcoming productionchallenges this new inclusion will provide arelaxed venue for reviewing and discussing acomprehensive range of the latest globaldevelopments and industry directions and anappropriate launching platform for further tradeand business opportunities.

The forum, which will be attended by CEOsand senior managers from the major players, willalso feature presentations from Zaid Khamis Al-Siyabi, Director-General of Oil & Gas Explorationand Production at Oman’s Oil and Gas Ministry,and the GM of BP in Oman, Jonathon Evans.Other highlights include Fareed Al-Asaly, Head ofG20 Energy and WTO Groups at KSA’s Ministry ofPetroleum and Mineral Resources discussing therole of alternative energy sources with IvanoIvanelli of the Dubai Carbon Centre of Excellenceand Vahid Fotuhi from BP.

SPE EOR Conference As well as providing a pair of focused trainingworkshops for regional engineers (covering EORgeomechanics and Chemical understanding of EOR)the associated but independently organised, by theSociety of Petroleum Engineers (SPE), EORConference will cover the following detailedaspects of what is now one of the oil and gasindustries’ – mature operators anyway - hottestgeneral topics; some subjects will be covered inmore than one session:

6 Chemical EOR6 Low salinity water flooding6 Thermal EOR6 Reservoir simulationwww.ogwaexpo.com/

OGWA 2010 attracted over300 local and international

companies showing anextensive range of products,

services, equipment andtechnologies

50

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

OGWA on track for

eighth edition


The First Stainless Steel Welded Pipe Mill in the Middle East

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6 Heavy oil6 Laboratory EOR6 Carbon dioxide6 Surveillance and monitoring6 Human capability requirements6 Technical/operational/economic challenges6 Gas injection of project implementation6 Well design6 Individual case studies

Major EOR projects currently being implemented in the Sultanate andlikely to be reviewed at this separate event include a package of newfacilities for the Amal Steam Surface Construction scheme, completerevamping of the Raysut terminal and the large Sohar Refinery expansionproject, which will increase daily throughput capacity from 116 to187,000 b/d, and output of naphtha as well. Other ongoing projects whichloosely come under the EOR category include the massive Duqmdevelopment project outlined above, the Mukhaizna Thermal Floodingscheme, thermally assisted gas/oil gravity drainage at Qarn Alam,miscible gas injection at Harweel, and polymer flooding as an EORtechnique (Marmul location).

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

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

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

And added Mr Patrik Haliden, General Manager of a local globalshipping and logistics business, after the doors had closed on OGWA2010: “It was yet another opportunity for GAC Oman to be present in anevent which attracted people connected with the oil and gas industryacross the world.” ■

For full information visit www.ogwaexpo.com or call Omanexpo on +9682466 0124 ([email protected]). For detailed information about theTechnical Conference including speakers and timings visitwww.spe.org/events/ogwa


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


52

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 MiddleEast - OGWA in Muscat.Dover Corporation acquired Oil Lift Technology in October last year that enabled the UScompany to expand its presence in progressive pump market.Oil Lift Technology manufactures artificial lift systems for the oil and gas industry. It specialisesin progressing cavity pump systems. Oil Lift products include wellhead drives, Rod-LockBOPs©, progressing cavity pumps and remote power units.Progressive cavity pumps are one of the fastest growing segments within the artificial liftmarket. Oil Lift products are used extensively in artificial lift applications around the world, andthe company has developed a strong reputation for innovation and customer service that hasenabled it to become a market leader. Oil Lift employs over 150 people in facilities within Canada, the US, and Australia. Thecompany has a strong international focus with significant activity in Latin America and theMiddle East.

MOTT MACDONALD has been present in Oman for44 years and the UK based firm enjoys a strongtrack record of successful projects. Oil ReviewMiddle East spoke to Vinod Shah, managing directorof Mott MacDonald’s Oman business, about theirpresence at the forthcoming OGWA event inMuscat.The Oil and Gas West Asia (OGWA) exhibition is oneof the largest events of its kind in Oman. All themajor oil companies will be represented and Shahbelieves OGWA 2012: “Will provide us with a greatopportunity to showcase our skills and expertise anddiscuss the west Asia oil and gas sector.Shah added: “We have been participating at thisevent for several years and given the positiveoutcome of previous years, we are excited to beparticipating once again.” Mott MacDonald’s Oman operations began in 1968and since then they have been providing the localoil and gas industry with their services whileworking with major IOCs and NOCs. “Although we enjoy a strong local presence andhave a strong track record in Oman, the market hasbecome very competitive since the country openedup to local and international oil and gas players. Itis therefore crucial for us to have a presence at theshow and reaffirm our commitment to Oman, whichis what sets us apart in the competitive arena,” saidShah.Mott MacDonald will be showcasing a number of

products/services at the show. Inparticular, the UK company willbe showing its: “prestigious EORprojects recently delivered anddemonstrate how implementingsuch technology can add newlife to the oilfield by greatlyimproving its recovery factor andoutput. In addition, besides thetraditional oil, gas andpetrochemicals services andskills we are renowned for, wewill show that being a globalmultidisciplinary companyallows us to work in other keyinfrastructure areas such aswater, transport, building, power,and environment. We often drawfrom our multidisciplinary skills for the delivery ofmore complex projects,” stated Shah.Mott MacDonald will be exhibiting at stand 101 andShah encouraged anyone attending OGWA this yearto come and visit to learn more about one of thelongest serving and experienced engineeringconsultancy firms in Oman. From early projects atYibal and Fahud oilfields to more recent EORprojects. They have had a long term relationshipwith Petroleum Development Oman as well as morerecent partnerships with other clients including Oxy,Daleel, OGC, ORPC and OLNG.

Shah concluded by talking about the outlook for theoil and gas industry in Oman. “The outlook for theOman economy looks good. The government hasindicated an increase in the oil and gas budget andplans to invest huge sums in the industry over thenext five years through a combination ofgovernment and private investment.”“Our business in Oman is in very good shape anddespite the strong competition from new andinternational players we sustain a steady growthyear on year. Last year we delivered an excellentperformance for the Group,” Shah added.

Mott MacDonald’s strong track record in Oman

BP OMAN IS exhibiting at OGWA 2012 and afocus of its presence is to talk aboutchallenges and solutions in developing tightgas resources. BP’s stand will describe the company’sapproach to careers and skills development, toOmanisation, and to community investment. Italso explains BP’s presence in the Middle Eastand gives the latest information about theKhazzan Project.

BP has been operating a pilot Extended WellTest at Khazzan since March 2011, helping todemonstrate the potential of a much largerscale development. BP’s pioneering worktakes technology and expertise used toexploit challenging unconventionalresources elsewhere and applies them todevelop one of the Middle East’s largest tightgas 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 itgoes ahead, will involve drilling around 300wells. The first phase of the project will targetreserves of up to eight trillion cubic feet withfirst gas delivered in 2016. With full fielddevelopment, BP would look to achieveproduction of around 1.2 billion cubic feet ofgas per day – equivalent to about a 33 per centincrease in domestic supply.


BP Oman to provide update on Khazzan Project

Oil Lift Technology prepares for OGWA

Vinod Shah, Managing Director at Mott MacDonald Oman





ADIPEC 2012 will take place from 11-14 November 2012 at the AbuDhabi National Exhibition Centre and is supported by key industryplayers such as ADNOC (Abu Dhabi National Oil Corporation) and theUAE Ministry of Energy.Two thirds of the world's known oil reserves are concentrated in theregion and Abu Dhabi plays a vital role in shaping the industry'sdevelopment representing 95 per cent of total oil reserves of UAEmaking them one of the world's top five oil producing nations. The oilreserves in the UAE currently stand at 98 billion barrels and productionstands at over 2.6mn bpd. With an annual production at 50 billion cubic meters of natural gas, theUAE 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 companiestaking part. Unprecedented international demand meant that theexhibition expanded from just 12 halls to include the concourse andoutdoor exhibits as well. Around US$4 billion worth of deals were signed during ADIPEC 2010,and over 41 per cent placed orders/purchased items not consideredbefore attending ADIPEC. In addition, 27 per cent of visitors to ADIPEChad a budget of over US$ 1mn to spend at the show. According to theshow organisers, visitors said ADIPEC was the place to sourcesuppliers, and evaluate products/services from global markets. ADIPEC2012 is an ideal venue for new-to-market firms interested inparticipating in the Middle East offshore and onshore gas development,as well as those seeking to promote their technologies and services topotential contractors and end users. ADIPEC is the largest oil and gasevent in the Middle East and will once again play host to more than

30,000 visitors, 2,000conference delegates and1,500 exhibiting companiesall under one roof for fourdays of dedicated networking. In 2010, over 40 companiesfrom Canada participated atADIPEC. This year, there willonce again be a CanadianPavilion of 500 sqm. The costfor a fully constructed standis CD$ 690 per sqm(minimum of 12 sqm) whichwill include a table, twochairs, three shelves, power,lighting, carpets, name board,and entry into the Canadianexhibitor directory.

For further information,contact:Venky Rao15-4135 Shipp Drive, Mississauga, ON, L4Z 0A7, CanadaTel: 1 905 896 7815 Email: [email protected] Arafat, Trade Commissioner, Embassy of Canada .Tel: +9712 6940334,email: [email protected]: www.international.gc.ca/abudhabi

THE 19TH INTERNATIONAL Caspian Oil & GasExhibition, incorporating refining andpetrochemicals, will take place on 5th to 8thJune 2012 in Baku, Azerbaijan. The Caspian Oil& Gas Conference, meanwhile, will be held atthe Hilton Hotel, also in Baku, from the 6th to7th June. The event serves as an annualmeeting place for regional and international oiland gas leaders and representatives from the

Ministry of Industry and Energy of Azerbaijanand the State Oil Company of the AzerbaijanRepublic (SOCAR). The Caspian Oil & GasExhibition and Conference is held annuallyunder the patronage of the President of theAzerbaijan Republic, HE Ilham Aliyev, and isalso officially supported by the Ministry ofIndustry and Energy of Azerbaijan and SOCAR.Last year’s event saw the participation of 285exhibitors from 30 countries and there were5,166 visitors.Azerbaijan has capitalised on its largehydrocarbon resources for over a decade nowand has actively encouraged direct foreigninvestment in its oil and gas industry. Thisinvestment has revitalised the country’s oilsector through the development of large-scaleprojects and the refurbishment of existingfacilities. With the completion of new pipelines,notably the BTC (Baku-Tbilisi-Ceyhan) and BTE(Baku-Tbilisi-Erzurum) pipelines, Azerbaijan hasnot only guaranteed secure routes to market forits oil and gas reserves but also positioned itselfas one of the largest producers in the Caspianregion and a potential transportation hub forother Caspian littoral states includingKazakhstan and Turkmenistan. The majority ofoil production growth in Azerbaijan has beenprovided by the Azeri-Chirag-Guneshli (ACG)field while the majority of the country’s natural

gas is produced fromoffshore fields. The bulkof Azerbaijan’s futurenatural gas productionis expected to comefrom the developmentof the large Shah Denizoffshore natural gasand condensate field.The Caspian Oil &Gas Exhibitionprovides a platformfor local and international oil and gascompanies to display the latest technologies,developments in the regional energy sector andshowcase current projects. The event hasenjoyed an annual growth in show space and anincreased level of participation by majorinternational oil and gas companies. TheCaspian Oil & Gas Conference provides a forumfor international policy makers, representativesfrom the Ministry of Industry and Energy ofAzerbaijan, international governmentrepresentatives and leaders of commercial oiland gas companies to discuss the latestdevelopments and market trends in the Caspianand Caucasus region. Over two days, plenarysessions and round-table discussions, organisedin conjunction with SOCAR, will bring togetheraround 500 delegates and over 50 speakers.

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www.adipec.com

Canadian firms gearing up for ADIPEC

Continuing to expand in the Caspian

www.caspianoil-gas.com

S12 ORME 3 2012 Innovs 1_Layout 1 05/04/2012 15:43 Page 55

56 Oil Review Middle East Issue Three 2012

ARTIFICIAL LIFT COMPANY, in collaboration with the Shoaibi Group,announced the successful installation of the first Rigless electricalsubmersible pump (ESP) string installed in the Middle East withSaudi Aramco.The installation was performed in one of Saudi Aramco’s fields andcomprised of a 134HP Rigless ESP system with a 6000 barrel-per-daypump. The system includes the Artificial Lift Company proprietaryPermanent Magnet Motors and Wet Connect system. The unit wasinstalled at a depth of 6,119 feet and included the installation of adownhole ESP gauge, packer, and subsurface safety valve assemblies.Saudi Aramco has provided a platform for further installationsthroughout the Middle East with several operators already showing adesire to use this technology. Artificial Lift Company’s Rigless ESPtechnology provides an opportunity for clients to retrieve the ESP stringwithout a rig, realizing significant benefits through cost savings on rigutilization and electricity expenditures, decreased downtime, and lessoil deferment.“Artificial Lift Company is honored to work with a company of suchhigh caliber as Saudi Aramco, enabling them to achieve a level ofoptimization consistent with their production goals,” stated AlanPetrie, Business Development Manager, Saudi Arabia, for ArtificialLift Company.“Technology like the ALC Advantage System (Rigless ESP Solution) andthe ALC Accelerator System (Permanent Magnet Motors for tubingconveyed deployment), combined with quality and service excellencewill profoundly transform how we produce ESP wells. The opportunity topartner with Saudi Aramco on this project, with continued support fromShoaibi Group, only furthers the impact that Artificial Lift Company ishaving in this important arena,” stated Alex Kosmala, CEO of ArtificialLift Company.

The success of this installation follows closely on three wells in Alaskawhere the Artificial Lift Company installation team’s experience nowestablishes them as a global leader in providing Rigless ESP technology.“This milestone installation validates Shoaibi Group’s ability to activelyidentify and invest in industry changing technologies that benefit energyproviders across the MENA region. We look forward to continuesupporting and providing ALC with all the necessary resources that willenable them to implement further successful installations across theMiddle East,” stated Mark Jenkins, Shoaibi Group Director, andappointed ALC Board member.

www.alcesp.com

First rigless ESP system installed

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OIL AND GAS producers in the region are experiencing thechallenges of producing resources laden with Hydrogen Sulfide(H2S) first hand. Working in this environment, companies mustaccount for the increased risks to the safety of workers andcorroding equipment in their project operating costs. Productrecovery and flaring during well operations have a significantimpact on the environment and are difficult to manage when H2Sis present. AMGAS Services Inc. has created innovative ways to

safely handle and process H2S.AMGAS offers a wide range of services, including H2S removal andcontrol measures aimed at mitigating the dangers associated withprocessing sour oil and natural gas. The company’s team ofprofessionals is trained in using the specialized and proprietaryequipment, chemicals and processes.“H2S is very dangerous, so the chemicals and equipment usedmust be dependable,” says January McKee, President of AMGASServices Inc. “For AMGAS, dependable innovation has alwaysmeant that chemicals and equipment have been tested andproven to be reliable”. Fluids containing H2S emit vapor equally as dangerous toworkers and the environment. Treating the vapors requiresdependable and innovative scrubbers to ensure the risks areeliminated and that the produced fluids can be stored,transported, processed or disposed. AMGAS has partnered withRutledge E&P Pte Ltd. who provides service for upstream drillingand exploration activities. Rutledge is based in Singapore and has operations throughoutthe Middle East.AMGAS’s strategic partnership with Rutledge provides completedetection, protection and removal technologies for H2Senvironments. The Canadian based-company has over 25 years ofexperience working to reduce H2S and other noxious emissions.Their scavenging and scrubbing chemicals are supported bypersonnel with the knowledge and experience necessary toreduce costs, environmental impact and increase safety.

H2S innovations reduce costs

www.am-gas.com



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ITT CORPORATION ANNOUNCED an Enterprise FrameworkAgreement with Shell Global Solutions in which ITT's Goulds Pumpsbrand will provide American Petroleum Institute (API) centrifugalpumps to support Shelloperations worldwide.Shell Global Solutionsis part of the ShellGroup, a global leaderin the energy andpetrochemical markets.Under the agreement,Goulds Pumps, aleading product brandof ITT and a leader inAPI pumps, will supplythese pumps in severalconfigurations to Shelloperations and affiliatesworldwide. TheEnterprise FrameworkAgreement is for fiveyears with an option foran additional five years.Shell applied acomprehensive process in selecting ITT Goulds Pumps, and thisagreement includes the development of common specifications,terms and conditions, and pricing. The Goulds Pumps brand is partof ITT's Industrial Process business, a dynamic business that isgrowing and expanding globally and has an extensive portfolio ofleading-edge technology that has served customers in the oil andgas, mining, chemical, power generation, biopharmaceutical, andgeneral industries markets for more than 160 years.

PARADIGM FLOW SERVICES has launched an innovative system for cleaningsafety critical fire mains in oil and gas installations. Pure-Flow can be injectedinto 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, whichcan restrict water flow, thin pipeline walls and also cause blockages in delugenozzles. Pure-Flow is a practical-to-use chemical for the remediation of firemains, and is also environmentally friendly. Using a pioneering deploymentmethod, Paradigm can inject the chemical treatment and take debris from a livefire mains system whilst maintaining the system pressure.

Paradigm has developed a unique method of generating the chemicalsolution in-situ which is then injected into the live fire mains in lowconcentrations. The chemical then rapidly removes biofilm and marine growthdeposits with no need for dismantling the pipework, as is the case in traditionalmethods of fire mains remediation, such as high pressure jetting. If there areinstances where isolation vales don’t work, these would have to be removedand treated separately before treatment of the fire mains could commence. Thisnew solution from Paradigm can be injected live into the system at any timethroughout operations even where the ring main valves no longer isolate.

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

STORAGE TANK AND gas holder specialist Motherwell Bridge is embarking ona ground-breaking alliance with professional services firm PROjEN and willbecome the first contractor to offer a complete suite of tank storage servicesfrom concept tohandover. The firmleads some of themost high profile tankand refinery projectsacross the UK, Europe,Middle East and Africaand the tie-up withPROjEN will allowMotherwell Bridge tooffer process design,engineering andmanagementexpertise for new-buildor remedial tank works without the need for separate project managers.Specialising in project management and professional services, PROjEN’salliance with Motherwell Bridge brings a collaborative approach whichemphasises forward planning, scope definition and risk management.

The revolutionary collaboration combines Motherwell Bridge’s reputationfor in-house design, refurbishment and new build on large diameter tanks withPROjEN’s project management and multi-disciplined engineering expertise toprovide efficient A-Z project implementation.

Tank servicing alliance

www.itt.com

KONGSBERG MARITIME HAS been awarded a significantoffshore automation contract with Daewoo Shipbuilding &Marine Engineering (DSME). The contract covers the delivery ofKongsberg Maritime’s proven Dynamic Positioning, thrustercontrol, bridge navigation, vessel automation, safety, risermanagement and environmental monitoring systems to twosemi-submersible drilling rigs (Cat-D).The two new build high specification semi-submersibles aredesigned for mid-water harsh environment in the NorwegianNorth Sea and have been orderd by Songa Offshore SEsubsidiary, Songa Rig AS, following a Letter of Award (LOA)from Statoil."This is what we call a 'Full Picture' solution from KongsbergMaritime. Our strategy is to take on more responsibility in thevalue chain by offering a full range of Integrated AutomatedMarine Systems. This contract was won as a direct result of thisapproach. Close collaboration with the customer and a commitment tounderstanding the extreme contexts in which our technology isapplied are important driving forces behind this award," saidGeir Håøy, President, Kongsberg Maritime.Kongsberg Maritime will commence deliveries, includingengineering services, to the DSME yard in Korea early 2012,with all key Kongsberg Maritime deliveries scheduled forcompletion by December 2012. Startup, commissioning and trials are scheduled to becompleted in Q1 and Q3 2014. The contract also comes with anoption for Kongsberg Maritime to deliver products and servicesfor two more semi-submersible drilling rigs."The competition is strong and we are very pleased to havesecured this contract. It is a clear demonstration of ourcapabilities in this field. I am also very pleased with the hardwork performed by our international offshore team,"concludes Tor Erik Sørensen, Executive Vice President,Kongsberg Maritime.


For oil and gas fire safety

Offshore automation contract awardedITT announces global supply agreement

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2012-02-24 14:00:58


QUICKFLANGE, ONE OF the industry’sleading providers of high performance pipeconnection systems, is to launch a series offixed cost ‘taster kits’ designed to stimulateinitial use of its own ‘cold’ pipe connectionsolution the Quickflange.

The new taster kits, which are beinglaunched in the UK and the Netherlands andwhich will be priced based on each installedflange, will allow operators to see thebenefits of the Quickflange for themselvesbefore making any longer-termcommitments.

Furthermore, operators will also be safein the knowledge that there will be noadditional costs from open-endedmobilisation or if a particular job is delayedor moved. Such delays can be particularlyexpensive with additional costs relating torental equipment and increased personnelrequirements. The Quickflange pipeconnection solution provides a fast,convenient, safe and highly cost effectivepiping solution equivalent in strength to awelded or mechanical connection. As ittakes place within a ‘cold-solutions’environment, the Quickflange solutiondoesn’t require heat sources in the sameway that welding does.

Fixed-cost ‘taster kits’

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INDUSTRIAL SCIENTIFIC, A leader in gasdetection as a service, announced theavailability of the Ventis™ LS multi-gasdetector as part of the Accenture LifeSafety Solution. Using Wi-Fi andlocation-based technologies to remotelymonitor those working in potentiallyhazardous environments, this wirelesssolution helps keep people safer. The Accenture Life Safety Solutionleverages the expertise of IndustrialScientific, as well as their unique GasDetection as a Service solution knownas iNet®.It also incorporates the leadingtechnologies and processes ofAccenture, AeroScout and Cisco. Thesolution is designed to continuouslymonitor employees working in plantenvironments across oil & gas,chemicals, petrochemicals, metals,mining, forest products and utilities.The Ventis LS has the ability to detectone to four gases, including H2S, O2,LEL, CO, SO2 and NO2. In potentiallyhazardous conditions, the instrumentalerts users through audible, visual andvibrating alarms.The instrument’s gas level information isthen transmitted over Cisco’s UnifiedWireless Network using the gasdetector’s integrated Wi-Fi Tag fromAeroScout.

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2012-02-24 14:00:58



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OIL REVIEW COVERED the launch of WesternGeco’s new UniQ* System Salesdivision 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 andlease its UniQ point-receiver land acquisition and processing system toother industry players.

The announcement was made at a special launch event duringGeo2012 in Bahrain. Sanjay Singhal opened by saying that the launch ofthe system sales division will usher in "a new era in the land seismicservice industry."

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

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

BenefitsBoff Anderson, Business Development Manager for UniQ product line,was at the launch to guide people through the main features and keybenefits of the UniQ system.

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

UniQ technology has been designed from the ground up and offersbetter seismic imaging through denser noise and signal sampling. TheUniQ platform is designed as an open-architecture system with acapacity 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 channelcapability means that our customers can lay out large super spreads.UniQ can also handle any type of simultaneous and high-productivitysource techniques, which makes these denser geometries cost effective.”

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

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

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

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

Time is always a key factor in any project and UniQ can help reducethe 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 delivermuch better quality data in a given timeframe.” Better quality data canresult in improved decisions in an exploration development cycle.

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

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

“We can see that the industry is moving towards high channel countsfor better signal sampling and high productivity source techniques for amore cost effective service,” said Anderson

Depth imaging is also becoming a standard and “we will see that theground roll, traditionally seen as noise, but recorded faithfully by point-receivers is actually signal with important information to help derive abetter characterisation of the near surface, which then helps deliver amore accurate velocity model.”

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

ChallengesWith industry adoption of high-capacity point-receiver seismictechnology accelerating, open availability of the UniQ system isexpected to lead to further growth.

“WesternGeco’s decision to make theirUniQ system available to anyone is to bewelcomed of course and as customers weknow you want to see increasedcompetition,” Mugharbel said.

Anderson explained that WesternGecowas making the system available to theindustry to accelerate the uptake of point-receiver acquisition technology and also tohelp realise the value of our investment byhaving it more widely implemented.

UniQ will be fully supported bySchlumberger’s research and engineeringorganisation, which will ensure that UniQwill be able to deal with all futurechallenges.

“UniQ technology is more than anacquisition system and we will also bemaking all of the spread design, datamanagement and single-sensor noisereduction and signal enhancementsoftware available,” said Carl Trowell,president, WesternGeco.

*Mark of Schlumberger

UniQ System available to all

The UniQ system



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TRELLEBORG WILL SHOWCASE its extensive product portfolio at the2012 Offshore Technology Conference in Houston this year.Emphasizing its product and material engineering focus, Trelleborgwill give sixpresentations at thecompany’s booth (No.5217) during the show.Trelleborg SealingSolutions is one of theworld’s leadingdevelopers,manufacturers andsuppliers of precisionseals and bearings.Trelleborg’s sealingsystems for the oil andgas industries aredesigned to cope withhigh-pressure, chemically hostile environments. Its products includeO-Rings, gaskets, hydraulic seals, rotary shaft seals, static seals, oilseals and pneumatic seals. Trelleborg Sealing Solutions willofficially release its comprehensive, all-new Oil & Gas ProductCatalogue & Engineering Guide at the conference. Trelleborg Oil &Marine Hoses is a leading supplier of innovative and field provenlarge-bore bonded hoses for crude oil, chemicals, LPG and LNGmarine transfer solutions. The company provides full serviceworldwide through the whole life cycle of the product – engineeringstudies, delivery of complete solutions (hoses and ancillaryequipment), on-site supervision and recommendations forinstallation, maintenance and repairs.

CAOMM HAS ANNOUNCED that it will bemaking a bespoke, remotely-operatedunderwater survey and inspection platformavailable to the Middle East market.

Following identification of a requirement foran integrated vehicle to perform survey andinspection of assorted assets from depths of upto 100m, through the intertidal zone to dryingheights, Offshore Marine Management haveconceived a unique approach to a problemwhich would usually require the deployment ofmultiple conventional ROV and diving spreads.CAOMM has been created from a joint venturebetween Controls and Applications Emirates(CAE) and Offshore Marine Management (OMM).

OMM has approached this problem fromthe perspective of a customer who wishes tominimise not only project costs but also risks.This, coupled with the ethos of producing asolution that is tailored to the task ratherthan employing an existing underutilisedasset, has led OMM to develop an integratedvehicle which is capable of working both dryand submerged.

The vehicle is a four wheel drive, all terraincrawler which acts as a platform forconventional survey sensors and also has thefacility to carry an onboard ROV. With full

independent suspension supporting each drivesystem, the crawler is designed to provide theoptimum platform for the onboard sensors.

These will be used to track and survey bothroute corridors as well as fixed assets,including pipelines and cables. The ROV is alsoavailable to be remotely deployed foradditional inspection of hazards, areas ofparticular interest or offshore installationswhich can be reached in a single journey fromthe shore.

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

Rigorous design criteria were developed andadhered to during development, ensuring thatthe crawler platform will be capable of workingin currents in excess of three knots, across alltypes of seabed terrain from soft sands, subseaobstacles to bedrock and up to 40° slopes.

System deployment to point of mobilisationwill be achieved using a single HGV. Fromthere, it may be loaded onto any vessel ofopportunity from a multicat to a DP 2 vessel.Use of a crane based LARS ensures little or nomodification of a host vessel is required, whilstcontrol and monitoring will be undertaken

from a standard ROV control van. The platformwill be operated using a bespoke softwaresystem which will provide both ROV andcrawler control.

The all inclusive capabilities of this singlepackage are designed to offer customerssignificant cost savings when compared withthe use of multiple conventional packages tomeet the survey and inspection requirementsof key assets.

With flexibility being a keystone of thedesign specification, positive feedback hasalready been received from Energy andTelecommunications customers. The system isscheduled for delivery in 2012 and,commenting on the development, OMM’sDirector of Survey & Subsea, Arron Burrows said:

“Importantly, this hybrid solution willremove the need for multiple vehiclemobilisations as is currently commonplace inthe offshore environment. We believe thatmany operators will therefore see this as acost-effective solution, avoiding the need foradditional equipment and personnel. It willalso be small enough to be easily-transportedwithin a multicat or dynamic-positioning (DP)vessel, yet remains highly adaptable andhigh-powered.”

www.trelleborg.com

THE RECENTLY OPENED Botlek Tank Terminal (BTT) at Rotterdamrelies on Rotork’s latest electric valve actuation technologies forautomated flow control and vital safety related duties associatedwith the import, export and storage of a varied range of liquid bulkproducts. Construction of the first phase of the terminal began inApril 2010 and was completed within budget and on time by thePolish company Polimex-Mostostal S.A. BTT has 34 storage tanks,providing a combined storage capacity of 200,000 cubic metres, ofwhich 130,000 cubic metres is earmarked for clean fuels and therest is for edible oils and biodiesel. The state-of-the-art terminal hasdeepwater berths including a 420 metre jetty that cansimultaneously accommodate two seagoing vessels and twobarges, operating 24 hours-a-day.Over 250 Rotork IQPro multi-turn and quarter-turn intelligentelectric actuators have been installed to operate the valves thatcontrol the routine movement of liquids throughout the site. Afurther 55 Rotork Skilmatic SI self-contained electro-hydraulicactuators have been installed in strategic areas on valves thatprovide failsafe Emergency Shutdown (ESD) protection frompotential accidents and spillages. All the Rotork actuators aremonitored and controlled on fully redundant Rotork Pakscan digitalbus loops, linked by three Pakscan P3 master stations to the site’scentral SCADA system.The Skilmatic SI actuators are equipped with integral circuitrydesigned to receive a separately hardwired discrete ESD alarmsignal that will override any other input and move the actuator tothe pre-determined safe position, even in the event of electricalpower failure. These actuators are situated on the inlet and outletports 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 logicsolvers to provide the site’s Safety Instrumented Function (SIF).


Innovative survey and inspection platform

Solutions for automated flow controlTrelleborg on show at OTC

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SCHLUMBERGER ANNOUNCED THE availability of its new PressureXpress-HT*reservoir pressure service and MDT Forte-HT* qualified, rugged, high-temperatureformation sampling and pressure system. These two services are the latest high-temperature additions to the Schlumberger reservoir characterization portfolioof services. “Providing a full suite of high-pressure, high-temperature (HPHT)evaluation tools is a major engineering focus within Schlumberger. These twotool systems expand ourcapabilities to deliverreliable downhole fluidanalysis, fluid sampling,pressure measurementand interval pressuretransient testing,” saidCatherine MacGregor,president, SchlumbergerWireline. Rated to450°F thePressureXpress-HT toolprovides accuratepressure gradients andoverall data quality notachievable by conventional high-temperature formation tester tools. The uniquedynamically controlled pressure pretest system in the PressureXpress-HT toolenables precise control of volume and drawdown rates. This now makespressure testing possible in tight formations common in HPHT reservoirs. Thetool design also eliminates the need for gauge temperature stabilization, thussignificantly improving overall operational efficiency.

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

The contract includes the provision of suitably qualified engineersfully trained in Under Pressure Leak Sealing Procedures and methodson pressurized piping systems, and additionally to provide allnecessary service equipment to perform Leak Sealing Service in Qatar.

Graham McKay, International Business Development Director ofUnique Wellube commented on this contract saying “We are verypleased with this opportunity to work with QAFAC and will ensure wemeet their expectations with high quality products and service”.

“We are always very careful in selecting our suppliers and arepleased to award this contract to Unique Wellube. We look forwardworking with them and building a long lasting business relationshiptoo” said Hussam H. Al-Natour who is head of Procurement at QAFAC.

Unique Wellube FZC are providers of specialist engineeringservices and products to a diverse range of industries. The company’srange of services is directed at maintaining plant operability, byallowing intervention work to be carried out with the minimum loss ofproduction, in a safe and cost efficient manner.

Utilising many years of combined experience, Unique Wellube’steam of professional graduate engineers and highly skilledtechnicians utilise operational experience backed by substantial R&D,to provide innovative solutions to meet its customers’ mostdemanding challenges.

Qatar contract for Unique Wellube

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

water treatment solutions

www.alderley.com

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www.slb.com

Delivering reliable analysis

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BAKER HUGHESHAS broadened itspipeline serviceportfolio toincludecircumferentialmagnetic fluxleakage (MFL)inspectiontechnology, whichenables pipelineoperators toidentify anomaliesin pipeline longseams and more effectively manage the risk associated with cracksin long seam welds and the overall integrity of their pipeline assets.The company recently acquired the assets andcircumferential/transverse field (TFI) MFL technology of IntratechInline Inspection Services Ltd. With circumferential MFL inspectiontechnology, Baker Hughes Process and Pipeline Services group canassist operators with locating specific pipeline seam threats, suchas hook cracks, lack of fusion and long narrow-axial corrosion. Thecircumferential MFL technology will now be produced in the largerdiameter pipeline sizes, complete with speed control and inertialnavigation capabilities.

LEVERAGING CROSS-INDUSTRY KNOWLEDGE and experience to deliveroptimal anticorrosive coatings, Jotun claims to have widened thetechnology gap with Jotamastic 90 - a step change in high-tech surfacetolerant coating solutions. The new Jotamastic 90 is one of the most technologically advancedsurface tolerant repair and maintenance primers in the market.Jotamastic 90 is a highly durable coating featuring benefits such asexceptional corrosion resistance, shorter overcoating intervals, wider topcoat compatibility and increased colour flexibility using Jotun's MultiColour Industry (MCI) tinting system. Jotamastic 90 has exceptional corrosion resistance and is suitable for themost severe environments. It has reduced drying time by up to 40 percent compared to existing products, thus reducing downtime andovercoating intervals.Jotamastic 90 offers compatibility with most topcoats, includingpolysiloxanes and two-component acrylics. The multicolour possibility ofJotamastic 90 also proves significant improvement of hiding power forstrong coloured topcoats. Improved wetting and penetrating abilities alsogive better intercoat adhesion. Investment in corrosion protection is about calculating the cost of thecoating over the lifetime of a project. The right decisions at new buildingstage and the correct choice of surface preparation and coating systemfor maintenance and repair is the key to maximize protection andoptimize the return on investment."The new Jotamastic 90 utilizes modern technology and materialsproviding excellent wetting properties, ensuring even better surfacepenetration and adhesion to the substrate and resulting in a durablesolution," said Lasse Isaksen, Product Manager Anticorrosives at JotunCoatings. According to Isaksen, different coatings have differentlifetimes. "The Jotamastic range offers great potential for savings throughlower surface preparation costs, and is one of the market’s most durablesolutions compared with other surface tolerant epoxies," said Isaksen.

www.bakerhughes.com

Pipeline inspection services

Anti-corrosive coatings


TTHIS ARTICLE DESCRIBES the evaluationof a new class of chemical compoundsfor use as environmentally acceptablecorrosion inhibitors. These water-soluble

chemicals were developed as thermally stableinhibitors to mitigate CO2 induced corrosion in lowand high shear environments. Furthermore, theseproducts were effective for mitigating CO2 inducedcorrosion in various laboratory test environments.

The performance of these new products iscompared to that of a highly effectivetraditional corrosion inhibitor. It was extremelychallenging to develop new green chemistriesthat can compete effectively against non-greenchemistries under a variety of conditions. Thesenewly developed chemicals were highlyeffective in mitigating corrosion, while yieldingmore than 99 per cent protection at low dosage

rates (tested at 10 ppm). This article alsodescribes secondary inhibitor properties such asoil water partitioning, and foaming tendency.

Governments and industry around the worldare realizing that environmentally friendlychemicals are important to our general well-being. It is important to replace the chemicalstoxic to humans and the environment with non-toxic or less toxic chemicals.


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

Tech

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Effective corrosion inhibitors

‘go green’‘Green’ chemistry reduces the use of chemicalsthat are hazardous to the environment

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

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Green chemistry, or environmentally friendlychemistry, prevents or reduces the use orproduction of chemicals that are hazardous tothe environment and human beings. Greenchemists search for ways and means to reduce oreliminate acid gas emission, production of wasteat the end of a chemical process, use of toxicsolvents, and creation of harmful by-products.

Many oil and gas producing formations yieldhydrocarbons, brines, carbon dioxide, and/orhydrogen sulfide. All of these are very corrosiveto metal tubing, pumps, casings, and otherproduction equipment. Corrosion is high inwells producing brine since they contain highlevels of dissolved acidic gases (such as carbondioxide or hydrogen sulfide), inorganic salts, orlow molecular weight organic acids such asacetic, formic, or propionic acid. Thesechemical components increase the corrosivity ofthe medium when dissolved in water atelevated temperatures.

Corrosion prevention of metallic surfaces isan important industrial task. When metallicsurfaces oxidize, metallic ions either convert tosoluble salts, insoluble metallic oxides,hydroxides, carbonates, or sulfides. Theoxidation of the metallic surface causes itsdeterioration and results in scale buildup. Thetraditional and most common way to reducecorrosion is to add a corrosion inhibitor to thecorrosive system. Corrosion inhibitors are water-soluble and/or oil soluble chemical compoundsthat inhibit corrosion by changing the surfaceconditions of the metal when added in smallquantities to an aggressive medium.

The traditional organic inhibitors forcorrosion are typically derived from aliphaticand aromatic amines, polyamines, imidazolines,and imidazoline salts, among others. Inorganiccorrosion inhibitors include chromates, zincphosphates, and silicates. Although thesecommercially available corrosion inhibitorseliminate or reduce corrosion on metallicsurfaces, they are harmful to the environment.

Operating companies, governments, and thepublic have become increasingly concernedabout the toxicity and environmental impact ofoil field chemicals; especially in offshoreapplications. In offshore operations such as the

North Sea, environmentally sound chemicals arevery important.

While countries like those in the North Seahave regulatory agencies that demandenvironmental testing and registration for allchemicals, other regions also see the benefitof using more environmentally friendlycorrosion inhibitors.

Numerous tests are performed on the rawmaterials utilized in corrosion inhibitorformulations to evaluate toxicity,bioaccumulation, and biodegradability. Corrosioninhibitors should be non-toxic to aquatic life,biodegradable, and reasonably water-soluble inorder to protect the marine environment.

Furthermore, the flash point of the solventand the solvent-evaporating factor of thechemicals should be considered in designingthese inhibitors as lower flash point productscan be fire hazards.

As a leading supplier of corrosioninhibitors, Clariant’s focus has always been todesign corrosion inhibitors with low impact tothe environment. This is a difficult taskbecause traditional non-green chemistries aregenerally more effective and less expensive.Development of environmentally soundproducts can compromise desiredperformance. Most nitrogen and phosphorousbased inhibitors currently used in our industrycarry inherently toxic properties. Therefore, itis indeed a challenge to develop chemistriesthat are benign to the environment andrelatively cost effective. The final goal ofClariant is to replace all current corrosionproducts with cost comparable chemistriesthat are both green and as effective astraditional non-green chemistries.

Two approaches to this dilemma aredescribed below. The first approach was todevelop synergistic effects by combining knownclasses of green bases. A series of productswere blended methodically. The secondapproach was to design new molecules that arepotential candidates as green corrosion bases.This has been achieved through collaborationwith an industrial partner. The first approach isto meet short term goals and the secondapproach is to meet long term goals. The

ultimate focus is to develop corrosion inhibitorsthat are more cost-effective than a particularproduct which has been very successfully usedin the North Sea region for more than a decade.This chemical is denoted as Chemical C. Thisarticle describes the development ofenvironmentally friendly corrosion inhibitors byboth approaches.

Clariant has been at the forefront of greenchemical development and has a vast array ofgreen and low-toxicity base chemicals. Afterextensive screening, one formulation (ChemicalB) out-performed the traditional product(Chemical C). Screening of formulations usingnewly developed compounds yielded a series ofnew chemical formulations. Out of this series,one product (Chemical A) was selected basedon its efficacy, water solubility and stability.These new products are not expected to createfoams or emulsions.

More than one hundred inhibitorformulations were screened as corrosioninhibitors at Clariant’s Aberdeen (Scotland)and Houston (USA) laboratories. They wereevaluated under several different laboratoryconditions. Two of the corrosion inhibitorswere new green blends (Chemical A andChemical B), and one was a pre-existingchemical (Chemical C) that has been widelyused in the North Sea area for more than adecade. Chemical A is a chemical whose rawmaterials were blended utilizing the newlydeveloped chemical compounds. Chemical Bis comprised solely from existing andapproved green intermediates already in use.Chemical C was primarily used in the testingto set a precedent of performance by a non-green corrosion inhibitor that we werestriving to meet or exceed with a greencorrosion inhibitor.

The Corrosion Inhibitor packages wereevaluated by several types of electrochemicallaboratory tests.

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


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Corrosion is a huge problem in theregional oil and gas sector


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deionized water. The synthetic oil used wasLVT 200. All tests were run with de-aeratedbrine and oil (90:10) that were continuouslysparged with 100 per cent CO2 gas. Aconstant temperature of 150°F was maintainedover the duration of the test using a hot platewith an integrated temperature probe. The RCEtest method was run at 2000 RPM. All testswere allowed a minimum of one hour tocollect a baseline corrosion rate prior to theaddition of the inhibitors. All corrosioninhibitors were added at 10 ppm based ontotal solution volume.

Under both high shear and high CO2saturation, Chemical A proved to be an excellentcorrosion inhibitor across a wide spectrum ofconditions. Chemical A showed a sharp drop incorrosion rate as soon as it was added to thesystem and continued to lower the corrosion rateas time progressed. Chemical B showed the mostaggressive drop in corrosion rate, surpassing evenChemical A initially, but eventually wasoutperformed by Chemical A after approximately14 hours. Chemical C was outperformed by bothChemical A and Chemical B

The tests were conducted in relatively highshear, and the results indicated both products Aand B out-performed the traditional Chemical Cat a very low concentration. This test was

repeated several times and the performanceresults obtained were very similar.

The second method we employed was RCEbubble tests. The RCE bubble test wasconducted with 3.5 per cent sea salt, 150°Fand with 10 ppm corrosion inhibitor chemical.The test was conducted to study thepartitioning behavior of the chemicals. TheRCE test equipment was set up exactly asdescribed above but the tests were conductedwith stationary electrodes. The only agitationwas by 100 per cent CO2 gas bubblingthrough the total fluid in the test vessel. Thebrine to oil ratio was 9:1 and 10 ppm of eachchemical was added to the oil phase of thesolution; allowing the chemical partition tobrine without much agitation. The corrosionrate of this static test exhibited the sametrend as shown in RCE aqueous tests. TheChemical A with newly synthesizedcompounds was slightly better in corrosionmitigation than Chemical B which is made ofexisting green intermediates. Bothoutperformed the bench-mark traditionalcorrosion inhibitor C.

Chemicals A and B were tested for foamingtendency in several oil field brines. The productsare not expected to foam. The laboratoryevaluation indicated that these products do not

create emulsions. Both products are soluble in3.5 per cent sea salt brine.

Clariant carries several effective greencorrosion inhibitors in the corrosion productline. The goal of this project was to developseveral chemicals that are environmentallybenign while being cost and performancesimilar to or better than an excellent bench-mark chemical from traditional chemistry. Thetest indicates that both green productsperformed better than the bench-mark chemical(Chemical C). The effective concentrations ofall three products are very close to each otherand Chemical A and Chemical B are expected tobe very comparable in the price range to thebench-mark chemical. With more than 99 percent protection at 10 ppm of each chemical,these chemicals can replace traditionalchemistries in the North Sea as well as aroundthe world where environmental restrictions arecurrently not enforced. ■

Authors: Nihal Obeyesekere Ph.D., ThenukaAriyaratna, Clariant Oil Services, 2645Technology Forest Blvd., The Woodlands, TX77381, USA and Alistair Kirkpatrick, ClariantOil Services, Howe Moss Place, KirkhillIndustrial Estate, Dyce, Aberdeen AB 210GS,United Kingdom


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AAS THE WORLD’S greatest oil and gasproducing region, the Middle East is anatural magnet for drillers and a keyfixture in the global rigs market.

And activity appears little changed in the regionfrom a year ago, despite the uncertain energydemand backdrop in Europe and elsewhere that isnow troubling key oil and gas producers such asSaudi Arabia, Kuwait and Iran.

In a January update, drilling rig analysts IHSPetrodata reported that there were 121 rigs in thetotal drilling fleet across the Middle East region,just two up from the 119 recorded in the samemonth in 2011.

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

IHS reported that 99 rigs of the total fleet wereunder contract in January, compared to just 90 ayear earlier. It represents a utilisation jump from75.6 per cent to 81.8 per cent, which, according tothe figures, is slightly above the worldwide average.

It is welcome news for the doom merchantsconcerned that the economic headwinds in Europeand beyond would drive down demand and activity.

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

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

rates from collapsing,” it noted in a Januarybulletin.

The latter statement suggests that the marketcould be more fragile without the uncertainty nowemanating from Iran and the spectre of a Hormuzclosure, even if short-lived.

Lamprell limbers upFor now, things are looking up for the region’sactive rig suppliers and drilling firms.

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

It maintains a healthy order book too, wortharound US$1 billion, stretching into 2014, plus abid pipeline worth US$4.2 billion as at the end oflast October.

The company is now targeting deeperpenetration in other regional markets such as SaudiArabia, Kuwait and Iraq although there remainsgood future potential in its core Abu Dhabistronghold with projects such as Upper Zakum,Satah al-Razboot and Umm Lulu.

Last year was one of expansion generally forLamprell, which completed the acquisition ofMaritime Industrial Services (MIS) in September, amove 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 costsynergies of around US$11mn per year.

The London-listed company now employs over11,000 people across six sites, with its primaryfacilities in Hamriyah, Sharjah, and Jebel Ali, plusSaudi Arabia.

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

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

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

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

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

Jack-up oil rigs are mobile platformspositioned to drill into the sea floor, typically usedin shallow waters.

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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



The new acquisitions - triangular hulls withthree 310 ft legs, and capable of drilling in watersup to 200 ft deep - will provide a significant boostto NDC’s already busy fleet.

The year before, the company committed todoubling its then 28 onshore and offshore drillingplatforms over the next few years.

Another NDC rig, al-Bzoom, which had beenundergoing significant refurbishment works - againby Lamprell, this time at its Sharjah yard - was alsore-delivered in October 2011, further enhancingthe fleet.

Likewise, Kuwait Drilling Company’s growingfleet has served Kuwait’s prized oil industry formore than four decades.

Over the last five years or so the company haseffectively quadrupled its operations and itcontinues to expand rapidly.

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

The world’s biggest private drillers are also

enjoying the benefits of some stable work inthe region.

Noble Corporation of the US has about a dozenoffshore rigs dotted around the Gulf, operatingprincipally in Saudi Arabia, Qatar and the UAE.

The company successfully negotiated new dealson a number of rigs coming out of various shipyardstowards the latter part of 2011, mainly with SaudiAramco; some of these contracts now carry onthrough to 2014.

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

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

According to a report, The World Land DrillingRig Market Report 2011-2015, collated by energyconsultants Douglas-Westwood, the region stilloffers high potential singling out markets such asSaudi Arabia to see an increase in the number ofactive rigs.

“Substantial increases in production will seestrong growth of drilling activity in China, India andIraq ... while investment in enhanced oil recoverytechniques in Saudi Arabia and Kuwait are expectedto boost productivity in some of the world’s largestmaturing fields,” the report states.

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

The facility can be tailored to meet thespecifications of one-shot well exploratory drillers,through to larger contractors conducting significantdrilling operations across Iraq, reckons SimonBoxall of Marsh’s energy practice.

“This facility enables all contractors, from smallindependents through to global firms, to pioneerthe development of Iraq’s oil economy,” he said.

Drilling services US drilling giant Halliburton has stepped up itsinvolvement in Saudi Aramco’s huge Manifa project.

The project has been running with one rig, but itoriginally targeted 10 rigs for the offshorecomponent, which Halliburton announced when itwon the contract nearly four years ago.

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

The US contractor is also working on a five-yearturnkey drilling contract in South Ghawar, withwork in Uthmaniyah, Haradh, Hawiyah andShedgum.

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

Other international drilling service companieshave made great efforts in recent years to getcloser to local markets.

In Saudi Arabia, this has meant foreign servicesfirms linking up with local engineering specialiststo gain the best chance of accessing future work.

One thing seems certain: the increasingcomplexity of upstream work suggests that therewill long be a role for these companies in theregion, despite the trend to bolster local skills andindigenous employment.

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

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

Oman too, while keen to foster its‘Omanisation’ policy, faces equally toughchallenges in the field, as it gets to grips with itstight gas potential, in partnership with the likes ofBP and Occidental.

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

As long as their skills, technology andexpertise are in demand, then the Middle East islikely to remain a vital source of work for thedrillers, rig contractors, and services providers ofthis world. ■


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




HHONEYWELL PROCESS SOLUTIONS has been involved in all aspectsof oil and gas, from upstream (offshore and onshore) todownstream facilities (gas processing, refining and petrochemicalplants), 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, HoneywellProcess 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 adiverse portfolio of products and solutions to the process industry. The real focusis to push towards integration so that the company can provide high addedvalue solutions to customers.

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

“Honeywell portable gas detectors analyse atmosphere gas continuously toinform about safe environments for operators,” said Belhadj. “Thecommunication is established wirelessly with the Experion Control Systemwhich displays continuous gas analysis results and provides the operatorlocation within the plant in a dynamic fashion. This innovative portable deviceaugments tremendously operator’s safety.”

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

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

“Wireless is certainly the direction we are taking and there is a growingdemand in the region,” said Belhadj “Wireless is one area of focus for growth andwe are continuously looking at improving our existing technology with wirelessproducts 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 toaddress this through new technologies and innovation. R&D is a major focus ofour business and although the world is going through economic difficulties,Honeywell has not stopped investing in new products through its powerful R&Darm. We believe it will help the company to be better positioned as atechnology provider now and in the future.”

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

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

graduates from top universities are hired and trained thoroughly by Honeywellto 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 andwe are fully prepared to go after this business,“ said Belhadj. ”Honeywell hasinvested in a Centre of Excellence for Advanced Solutions based in Doha toserve the Qatari market and other GCC countries. Our objective is to remaincloser to Honeywell end users and act/support locally in order to growcustomer satisfaction and our business. Qatar is viewed as a key area of growthfor the coming years.”

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

“We have invested in world class facilities, offices and project areas at theDaharan Techno Valey (DTV). This shows the importance of the Saudi market forHoneywell,“ 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 termcommitment to the Saudi marketplace.

“Honeywell has first class training facilities located at DTV dedicated forSaudi Arabian customers. There is also a strong focus in partnering with keyuniversities such as King Fahd University of Petroleum and Mining (KFUPM) totrain students on Honeywell Technologies and develop strong futuregenerations of skilled engineers. In addition, Honeywell has implemented theJetPro programme, targeting new graduates in engineering disciplines.”

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

“We have opened offices in Baghdad and Basrah with resources locally basedand operating in Iraq,” said Belhadj “Our goal is to keep focusing on this marketand 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 tobring 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 addressthe challenge to build knowledge and skills in Iraq, Honeywell’s Basra officewill host a full training centre, displaying most of Honeywell’s automationsolutions 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; howeverwe have developed projects and engineering capabilities in all GCC countries toimplement projects and support customers locally,” said Belhadj.

The company’s level of investment in the UAE is increasing year after yearand Honeywell is about to open a large, world class Customer EngineeringCentre 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 hiringaggressively to supply skilled resources to the large volume of projects we aredealing 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 megapetrochemical plants announced for Saudi Arabia and Qatar which bring moreexcitement and energy to our business.” n

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

Honeywell outlines plans for

closer integration




WWHILE A 42 per cent increase in oilreserves is projected by 2030, thenatural gas sector is also enjoyingrapid growth, with the

International Energy Agency (IEA) forecasting thatnatural gas usage could double over the next 25years and account for a quarter of the world’senergy demand. However, increasing volumes donot necessarily mean increasing profits: today’s oiland gas companies need to improve control oversite performance and maximise productionefficiency if they want to achieve their financialgoals. The evolution of exploration and productiontechnologies is fundamental to increase productionwhile cutting costs, but relevant results can beobtained by revising data management processesto ensure that decisions are made as quickly aspossible and are, above all, based on consistent andreliable information.

Real-time production monitoring can beaccomplished successfully through acomprehensive and secure approach to datacollection, transport and analysis. Companies canunlock the value of information coming from theproduction workflow only if they have a solidinfrastructure to collect data from wells, refineries,production plants, pipelines and facilities. They thenneed to streamline this huge amount of informationinto their ICT systems, where it will be stored andprocessed in order to extract key and relevantinformation to increase efficiency and preventproduction losses.

The challenge of condition monitoring is evenmore complex if we consider that oil explorationinterests tend to move to harsh areas, such asoffshore or in the Arctic, where the highest volumesare expected. As for natural gas, conventionalsources will continue to represent the greater partof global supplies, but unconventional sources(shale gas or coalbed methane, for instance) willbecome increasingly important, thereforereinforcing the need to strictly monitor production.

So what is the best way to collect and transportdata coming from remote and even hazardousenvironments? In many cases, wired infrastructuresare already in place, and companies are unlikely toupgrade the network or add new data points due tothe additional cost. In a typical oil or gas facility,thousands of sensors and data points are needed toensure proper asset monitoring, with hundreds ofthousands of metres of cables used to connect thesedevices. If a brand new offshore platform hasapproximately 800-km of wiring, for example, withthe cable costing from US$120 to US$6,000 per

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

Maintaining wired process and sensor networksmay prevent companies from successfully dealingwith market demands or regulatory changes,however. Such changes may require increasedperformance and efficiency by increasing datacollection frequency or installing additional datapoints (ie to monitor emissions or new securityparameters). Traditional infrastructures are oftencomplex to expand or integrate, especially in hard-to-reach locations or harsh environments wherewired connectivity and wired networks can provedifficult to install, unreliable, too expensive orsimply unviable.

Wireless sensor networks can offer oil and gascompanies immediate and measurable benefits,including improved performance, greater flexibilityand reduced costs for installation and ongoingmaintenance. Wireless data acquisition andtransmission allow companies to have deeper, moregranular and accurate information from productionassets, therefore enabling effective plantmonitoring and supporting real-time decisionsthanks to the ability to feed all data directly intocorporate ICT systems.

As for the initial investment, a wirelesstechnology project can cost up to 50-70 per cent lessthan the wired option – considering hardware/materialcosts, engineering, installation, and globaladministration and management. There are severaladditional benefits as well, including: increasedoperational reliability and system uptime, increasedoperator and engineer productivity, improved assetutilisation and personnel safety and many others.

Of the several options available on the market,the best approach seems to be to go for openstandard, scalable and vendor-independent wirelessnetworks, so as to offer the best return oninvestment. No changes to existing data pointsneed to be made, for instance, allowing wirelessdevices to be implemented directly over the currentsensor infrastructure without requiring anyinfrastructure upgrade. This allows one network tobe built and ‘plug and play’ applications addedwhen needed at a fraction of the initial cost.

RF penetration, noise immunity, dynamicadaptation of network topology should be evaluated,since both parameters are particularly critical forreliable data transmission in oil and gas plants.Industrial wireless sensor network solutions generallyuse RF transmission on 2.4 GHz or above, which oftenproves to be inefficient in congested environments

and features a low penetration factor. Solutions basedon IETF open standards – such as 6lowPAN – on sub-GHz ISM band with full mesh topologies should bepreferred, as they grant higher penetration, noiseimmunity and dynamic adaptability to changes in thesurrounding environment.

Other benefits of wireless sensor networksolutions are more difficult to quantify, but are stillworth listing. As the system grows and more pointsare monitored and additional applications added,more data will be added to the companyknowledge systems; if the choice has been for abidirectional, M2M wireless network, instrumentcalibration and equipment diagnosis can beperformed remotely and more often – thusreducing equipment failures or forced shutdowns.

Another benefit is that most valid wirelesssensor network solutions require no software toinstall, no heavy server side operations and verylittle maintenance. In brief, they provide almostunmanned deployment coupled with a self-organising, self-healing, adaptive and fault tolerantnetwork. This is important for all industries, butparticularly relevant for oil and gas companies.Considering the harsh locations where plants are

Wireless sensor networks can offer oil and gascompanies immediate and measurable benefits

Of the several optionsavailable on the market, thebest approach seems to be to

go for open standard,scalable and vendor-independent wireless

networks

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

The benefits of wireless

sensor networks



usually installed, shrinking workforce and budgetconstraints, no complexity in implementation, rollout and maintenance processes can be afforded.

Authentication, authorisation and strongencryption – ie, security - complete the set offeatures together with an extended range oftemperature and hazard/explosion safe hardware

and web-based management applications to furtherstreamline configuration and management. Ultralow power technology coupled with long lifebattery operation (more than eight years) helpfurther to streamline labour and personnelintervention and overall efficiency.

Selecting a wireless sensor network that isready to scale up from narrow band to broadband tolink data to the HQ is an attractive solution, offeringconnectivity in typical oil and gas plant locations,where landlines are unreliable, difficult to access ornonexistent. Working with a satellite networkprovider, or virtual network operator, is aninteresting option to consider when developingtailored solutions and, if necessary, hybridinfrastructures for business continuity applicationsand redundant communications.

Due to the complexity of real-time productionand condition monitoring within the oil and gasindustry, wireless sensor network solutions can beparticularly successful in providing an effectiveapproach to data collection and transportation,

increasing overall plant efficiency. Thanks toinnovative wireless sensor network technologies, oiland gas companies have the opportunity to utilisethe value of all of the information coming from theirassets and production workflow. Lessons from thismarket are useful and can be applied to allindustrial organisations that have dispersed plantsand facilities that need to be monitored, however. n

Gianni Minetti is President and CEO of ParadoxEngineering SA, and founded the company in 2005.Paradox Engineering SA is a Swiss company whoseportfolio includes industrial wireless sensornetworks, smart metering solutions, global virtualnetworks for companies where smart grid, energymanagement, condition and remote monitoring,industrial process monitoring, engineering andtelemetry projects require future proof and costeffective solutions to unlock the value of data.Paradox Engineering SA acts as a global provider ofturnkey solutions and technologies through aconsolidated network of strategic partners.


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COLORADO SCHOOL OF Mines, Penn StateUniversity and the University of Texas atAustin announced a new training initiativeto support the rapidly growing shale naturalgas and oil development sector. Thetraining programs created under theinitiative will be led by the faculty at eachacademic institution and are designed toensure that regulators and policymakershave access to the latest technology andoperational expertise to assist in theirimportant oversight of shale development.ExxonMobil and GE, two of America’sleading energy corporations, todayannounced they would each contributeUS$1mn to this new educational initiative.“Regulators have said that the need forincreased training is one of their highestpriorities due to the rapid expansion ofshale resource development and theequally active evolution of technologiesand best practices in the field,” said GaryPope, director of The Center for Petroleumand Geosystems Engineering (CPGE) at TheUniversity of Texas at Austin.To meet this demand, CPGE, whichprovides engineering leadership andtechnology innovation related to energyand the environment with special emphasis on the production ofhydrocarbons 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 ourpartnerships and our scope to create a new training program forregulators in the oil and gas industry that is collaborative andinterdisciplinary,” said Olson.Thomas Murphy, co-director of the Penn State Marcellus Center forOutreach and Research, said, “The Shale Gas Regulators Trainingprogram affords the university a unique opportunity to furtherdevelop shale gas best management practices and to offer newregulators the chance to learn the latest science-based concepts

related to geology, petroleum technologyand environmental quality. Penn Statelooks forward to providing developmenttraining that will help ensure a strong, yetconsistent, regulator process across theAppalachian Basin.”Colorado School of Mines President M.W.Scoggins said, “Colorado School of Mines’focused mission to educate the nextgeneration of engineers and appliedscientists fosters a natural partnership inthis consortium. Our specialized curriculumand research program centered onresponsible resource development ishelping to enhance global understanding ofour most pressing earth, energy andenvironmental challenges.”Added Colorado School of Mines’ Dr. Azra N.Tutuncu, who is director of the school’sUnconventional Natural Gas and OilInstitute (UNGI) and Harry D. CampbellChair in Petroleum Engineering, “TheUnconventional Natural Gas and OilInstitute at Colorado School of Minesprovides training for developingunconventional resources in anenvironmentally sound, safe andeconomically viable manner - the oil and

gas industry as well as state and federal regulators and policymakersbenefit from this expertise.” The series of courses, which will primarily focus on the developmentof 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, includingwater treatment and management, waste treatment and management,air emission control technologies, spill prevention and planning andresponse; and6 Federal and state oil and gas regulatory requirements, including

permitting and reporting, plus compliance assessment.

Hydraulic fracturing - ‘proven technology’ supported by ExxonMobil and GE

Rex Tillerson



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

“Field-experienced specialistsfor all your stimulation operations worldwide.”

Fracture Technologies ConsultantsWeb: www.fracturetechnologies.comEmail: [email protected]: +447770524740

Fracture Technologies WellWhizWeb: www.wellwhiz.comEmail sales and info: [email protected] sales and info: +447770524740

GE and ExxonMobil believe that natural gas plays acritical role in America’s energy future. When used forpower generation, natural gas emits up to 60 per centless CO2 than coal. The integration of two proventechnologies - horizontal drilling and hydraulic fracturing- has opened up more than 100 years supply of naturalgas for US homes and business, creating anunprecedented pathway to enhanced energy security forthe country. Natural gas also enables more renewableenergy to join the power grid as next generation gasturbines help ensure grid stability by quickly ramping upand down to generate electricity when wind or solarpower is intermittent.“America’s shale energy resources are creating jobs andeconomic growth in regions across the country, andAmericans rightly want to know that these resources are beingproduced safely and responsibly,” ExxonMobil CEO Rex Tillerson said.“ExxonMobil is pleased to provide the resources to assist the schoolsin equipping regulators with the latest technical and operationalknowledge being applied in this growing sector.”GE CEO Jeff Immelt said, “Natural gas is dramatically changing the waywe power America, and GE is committed to its responsibledevelopment. We believe advanced technology, an expert workforceand smart regulation are the keys to America leading the world inshale gas development. As a technology leader in the energy sector,GE recognizes the importance of minimising a site’s environmentalfootprint while simultaneously increasing operational efficiency.”GE and ExxonMobil note that while hydraulic fracturing, horizontal

drilling and other technologies used to produce shale resources are notnew, they are being used today on a larger scale than ever before.Therefore, it is critical that regulators and policymakers have access toa sound scientific understanding of shale energy development and arefully aware of the technologies required to produce these resourcessafely and efficiently, while protecting the environment. That is whythe two companies have offered their support for the professionaldevelopment programs developed by these universities.GE produces nearly 40 technologies for the shale resource sector inareas such as mobile and fixed water filtration, flare gas capture andreuse, cleaner on-site power generation and demand-side solutionsthat create liquefied natural gas or compressed natural gas forapplications such as in-truck fleets.

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



FFRACTURE HEIGHT IS used by fracturingengineers to calibrate propagation models.An accurate height measurement reducesthe uncertainty of fracture pressure

matching, better determining frac length and width,stress profile across the target zone and its boundariesand fracture containment. This is particularly importantwhen there is concern with vertical penetration into anunwanted zone, or determining adequate zonalcoverage and reserve reserves. In most cases, fractureheight is measured using radioactive tracers which areblended into the proppant at the wellsite. Clearly thesecan present both a safety and environmental hazardand in some regions of the world their use isprohibited.

This paper presents innovative, environmentally responsible proppantdetection technology and associated logging techniques for propped heightmeasurement and/or proppant placement. Its non-radioactive nature eliminatesthe problems inherent in other tracing methods and, having no half-lifelimitation, is permanently detectable. It provides for conducting multiple post-frac logging at any time after fracturing, for initial assessment or to identifyintervals for re-stimulation later in the well life. The tracing capability doesn’tinterfere with the proppants’ strength or conductivity, assuring adequateperformance.

The theory and physical principles of the technology are discussed in detailand supported by case histories of its application in various environmentsaround the world.

The use of propped hydraulic fracturing has extended from early applicationin low permeability formations to all types of reservoirs, though the motivationsmay vary, most formations will benefit from hydraulic fracturing. Its scope todaygoes from fracturing extremely low permeability in unconventional reservoirs forcommercial viability, to low permeability wells for reserve acceleration, tofracturing high permeability unconsolidated formations for skin by-pass andsand control. These operations can be conducted in horizontal, deviated,vertical, open-hole or cased wells. The description below focuses onapplications in cased boreholes in vertical wells, however analogous conceptsare applicable to all frac situations.

Engineers design fracs, perforation placement and frac staging aimed attreating the whole targeted interval, but there may be zones within the desiredfracture interval which are ineffectively fractured, due to anomalies within the

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].

100

1000

10000

0 2000 4000 6000 8000 10000 12000 14000

Conductivity,md-ft

Stress, psi

HTNCC IDC 30/60IDC 30/60

HTNCC IDC 30/60 IDC 30/60In Size (-30 / +60) (%) 97 94

MPD, microns 493 490Crush (10k), % 1.2 1.1

ASG, g/cc 3.28 3.31BD, g/cc 1.88 1.86

Acid Solubility, % 3.0 3.4Shape, R/S 0.90/0.90 0.89/0.88

Turbidity, FTU 97 81Chemistry

Al2O3 72.4 73.9SiO2 15.4 13.9TiO2 3.0 2.9

Fe2O3 8.5 9.2Other 0.1 0.5

Tracer 0.4

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

Propped hydraulic fracturing reduces

environmental risks

Height Length Azimuth Environment Measurement Simplicity

Logging Speed

Forma�on & Comple�on

Fluid Interference

Mul�ple Tracer

Measurement �ming Cost

MicroseismicHydraulic Medium

Medium High Physical Method

Complex N/A N/A N/AWhile

fracturingHigh

Tiltmeters Hydraulic Medium

Medium High Physical Method

Complex N/A N/A N/AWhile

fracturingHigh

HTNCCPropped

HighModeled NO Inert Neutron Standard NO Possible

Any�me, Mul�ple

Compe��ve

RA TracersPropped

HighModeled NO Radioac�ve Spectral GR Standard NO YES

Days to Weeks

Compe��ve

RCTPPropped

HighModeled NO Resin

Neutron + Specral GR

Low Possible Possible Life of Resin Extra resin

coa�ng cost

Acous�cPropped

HighModeled NO Medium Std. N/A N/A Any�me Medium

Temp LogHydraulic

Low Modeled NO Medium Std. N/A N/A

Minutes to Hours

Low

Technique

Nea

r Wel

lbor

eFa

r Fie

ld

Measurement Type Features

Table 1 – Comparison of the various fracture geometry measurement techniques



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 andunfractured zones is very useful for planning remedial operations in the subjectwell and/or utilizing the information for designing frac treatments on future wells.

Fracture height measurementThe 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 isused to determine fracture propagation. These sensors can detect minutechanges in the earth’s surface contours or deformation downhole induced byfracture creation. These displacements can be interpreted to locate fracturedintervals, frac azimuth, length and height. In general, tiltmeter fracture map-ping only provides overall fracture dimensions and azimuths but not accuratedetails 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 thelocation of the microseism it is possible to estimate height and length of theinduced fracture. Like tiltmeters, microseismic is most suitable to determine fracazimuth 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 wastransported and placed there.

Near wellbore techniques. Most near wellbore technologies involve acousticmeasurements, 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 in-duced by the frac width are measured comparing pre and post-frac dipoleshear sonic tools. Data inversion allows determining propped fractureheight and width, as well as azimuth if crossed dipole is used.

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

6 Today, the most common nuclear methods use radioactive materials withhalf-lives of days to months mixed with frac fluid prior to pumping and agamma ray detector, usually with spectroscopic capabilities, to log the de-sired fracture interval. These techniques have the ability to spectroscopicallyresolve signals from multiple tracers and distinguish tracer from formationgamma ray emitters or those from deposits on tubulars. However, this tech-nique 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 oper-ational phases.

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

In another technique, one or more stable isotopes which can be activated bya neutron source are incorporated into the proppant with a resin coating. Afterdownhole placement of the Resin Coated Tagged Proppant (RCTP), a loggingtool is run which activates them. The gamma rays from the resulting decay ofthese activated “tracer” nuclei are detected and analyzed to identify theproppant, and hence the frac zones. This technique also has several limitations: 6 The neutron source will activate both these tracers and numerous other nu-

clei 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/boreholeare exponentially attenuated, reducing the depth of investigation.

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

Traceable proppantThis new nuclear technology addresses the difficulties described above. Lowconcentrations of a high thermal neutron capture compound (HTNCC) are addedto proppant grains in the manufacturing process . The proppant is pumped

Method 1Pre-Post CNT

Method 2Pre-Post PNC

Method 3Post CNL Only

OH CNL as Prefrac log

A�er producing well

While Produc�ng

Well

Altered Forma�on

Fluid Satura�on

Double casingVarying

Comple�on Brine Density

Brine switched to Gas in Wellbore

Texas YES YES YES YES YES YES YES YES

China YES

South America YES YES YES

Rockies YES YES YES YES YES YES YES

Africa YES

RegionPost frac log Changing Wellbore Environment

Harsh Condi�onsMethod

Table 2 – Worldwide HTNCC experience


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downhole and the HTNCC is detected using a Compensated Neutron Tool (CNT)or Pulsed Neutron Capture (PNC) tool which provide three different methods fordetecting the proppant: 6 Compensated Neutron Logging Tools. A conventional CNT (preferably the

same) with a continuous neutron source and one or more thermal neutrondetectors is run before and after the frac job. The resulting count rates andnear to far detector count rate ratios are recorded. A lower post frac count in-dicates proppant presence.

6 Pulsed Neutron Capture Logging Tools. Similarly the second method utilizesa run before and after the frac job. The decay curve count rate detected bygamma ray or thermal neutron sensors is recorded after fracturing the forma-tion. The pre and post-frac PNC parameters are compared and the formationand borehole thermal neutron absorption cross sections are calculated fromthe PNC decay curves. These comparisons identify the presence of proppant.In both the CNT and PNC methods above it is desirable to normalize the logresponses utilizing intervals logged outside the zone where induced fractur-ing is possible. It may be possible to eliminate the pre-frac log entirely if aPNC 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, wherethe near to far detector (N/F) ratios and the individual detector count ratesare utilized in the interpretation process. Despite CNT detector count ratesand N/F ratios being sensitive to formation porosity and fluid saturation, theN/F ratio is virtually independent of HTNCC proppant presence. If wellboreconditions are uniform, logged intervals not containing HTNCC proppant canbe used to develop a unique relationship between near and far detectorcount rate and N/F. A synthetic pre-frac log of CNT count rates can be gener-ated using these relationships to serve as the baseline for post-frac CNTcount 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 usedin some situations as the pre-frac cased hole log for the first method above, butthe open hole log must be normalized to match the response of the post-fracCNT in an interval without tagged proppant.

HTNCC proppant advantagesThe HTNCC is added to the ore used to manufacture ceramic proppant after theore is ground and before forming the pellets to ensure uniform distributionwithout need of coating or additives to attach it to the proppant substrate. Thisenables detection of the propped height, which is the portion of the fracactually contributing to well productivity and determining reserve recovery,rather than the hydraulic height discussed above. The HTNCC is incorporated insmall proportion , thus retaining proppant strength and conductivity whichdetermine proppant and fracture performance (Figure1).

Being a non-radioactive material HTNCC is environmentally andoperationally acceptable, has no limited half-life or suffers degradation, so ispermanently detectable and overcomes RA tracer limitations. Logging duringthe life of the well allows identification of unpropped intervals years in thefuture.

The HTNCC proppant changes the response of a neutron log when presentand is unaffected by formation type or chemistry. It is detected using standardneutron logging tools run at up to 1800ft/min and good acoustic coupling(cement bond) is not mandatory for Methods 1 and 2. The depth ofinvestigation of HTNCC is typically the same as that of the CNT or PNC toolsand similar to other near wellbore measurements.

A comparison of these fracture geometry measurement techniques is shownin Table 1. The green/yellow/red color-coding indicates high/medium/lowmeasurement confidence and benefit (green) or drawback (red) of thetechnology.

Field ExamplesThere is ample field experience of HTNCC proppant for propped fracturemeasurement and detection in the United States, South America, Africa andAsia. Diverse challenges in applying the technology include post-fraclogging timing and changes to the wellbore environment. Among the firstcategory were:

6 Post-frac logging up to two months after the frac due to wellbore accessproblems.

6 Wells flowed after the frac and prior to the post-frac log, with consequentchanges in formation fluid saturation complicating interpretation.

Variations in the wellbore environment included:6 Changes in wellbore fluid density.


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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 robustnessof the technology and the associated techniques summarized in Table 2.

The following case histories illustrate the use of the technology on aworldwide basis: 6 Rockies, USA. This well located in Wyoming contained 19 frac stages. Ten

deep stages were fractured with HTNCC tagged intermediate density ceramicproppant, one shallow stage with tagged lightweight ceramic proppant andthe remaining eight shallower stages with untagged proppant. The well wasoriginally logged with a CNT prior to the frac operation, again after the frac jobhad been completed and after several months of production. Wellbore fluidsvaried in the wellbore on each of the log runs and the borehole size and thecasing and liners present differed over the entire logged interval. Hence, for in-terpretation, the well was partitioned into several zones with constant well-bore 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 wellwas perforated from x278-286m. Fracturing occurred down 5-1/2” casingusing a cross linked fluid system with 54,000 lbs. of 20/40 sand followed by26,000 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 inthis example have low permeabilities (<1 millidarcy) and porosities generallyin the 10-15 per cent range. The well was fractured in several sets of perfora-tions using 300,000 lbs. of 20/40 light weight ceramic proppant tagged with aHTNCC. The well was producing 9.8mmcf, 111 bopd, and 30 bwpd during thepost-frac logging operation after a 12 day interval between the pre and post-frac logs.

6 South America. Results from this well are illustrated in Figure 5 and 6. Thiswell was in Putumayo basin, Colombia and targeted sands having 44 and 156ft. of gross thickness with porosity ranging between 8.3 per cent and 17.2 percent and absolute permeability between 10 and 1,500 mD. Frac height is amost critical design parameter to control in Juanambu but after 20 fracturejobs evaluation proved inconclusive, so the HTNCC proppant technology wasused with positive results.

Conclusions

6 The non-radioactive traceable proppant and logging methods for fractureheight measurement do not affect mechanical strength, conductivity, durabil-ity or density of the particles.

6 The neutron capture compound does not deteriorate so logging may be doneat any time in the well life.

6 One interpretation technique which has been successfully modeled and fieldtested compares pre-frac CNT log count rates with corresponding post-fracCNT values.

6 A second modeled/field tested technique utilizes only post-frac CNT data,wherein the observed CNT post-frac count rates are compared with those com-puted from the N/F count rate ratio for use when well parameters vary overtime.

6 Modeling data has also indicated that comparison of PNC captured data canbe effective in locating proppant tagged with high thermal neutron capturecross-section absorbers.

6 This new proppant has been successfully employed worldwide6 Successful cases performed in difficult conditions, derived from changes in the

wellbore and formation environment, demonstrate the robustness of the tech-nology and interpretation techniques.

6 None of these techniques employ radioactive tracer material, making them ac-ceptable under all environmental, operational and safety considerations. ■

This paper was prepared for presentation at the SPE/EAGE EuropeanUnconventional Resources Conference and Exhibition held in Vienna, Austria, 20-22, March 2012.


87Oil Review Middle East Issue Three 2012

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OIL REVIEW SPOKE exclusively to Brice Bouffard,Vice President Petroleum Consulting, Weatherfordand Bob Kuchinski, Business Development ManagerMENA, Weatherford about the recent launch of thecompany’s new business unit Petroleum Consultingand what this will mean for the petroleum industryas a whole.

After eight months of building up its core teamand strategy, Weatherford launched its new uniquebusiness proposition, at the GeosciencesConference and Exhibition (GEO) 2012 in Bahrain,namely its Petroleum Consulting business unitwhich will provide services to operators worldwidein the geoscience and engineering domain.

The global launch of the new service in Bahraindemonstrated that Weatherford is: “committed tothe long term development of the PetroleumConsulting business in order to provide industryleading consultative advice in alignment with clientdrivers. Its growth will be driven based on a threepronged strategy: investment in expertise and theirrounded development, innovation in differentiatedtechnologies and close collaboration with itsclients,” Bouffard said.

Kuchinski explained: “Petroleum Consulting isthe newest product line in our Reservoir andFormation Evaluation services.” It will offer clientsintegrated formation evaluation and wellengineering support and consultancy.

“It is set up to bring more brain power behindall of these formation evaluation services that werun. Petroleum Consulting is bringing more of theinterpretative brain power to our offering. It is thisnew emphasis on partnership with clients thatwill be a real focus of the new business unit,”added Kuchinski.

Skilled expertsPetroleum Consulting will operate on Weatherford’sglobal footprint. There are currently 300 employeesworldwide, including domain experts in the area ofunconventional resources, geomechanics, field

development planning, production optimisation,well engineering and project management.

Kuchinski commented: “We have a lot of reallygood technology coupled with great field techniciansthat can operate them. We have skilled experts andprofessionals in virtually every area, whether it beseismic, micro-seismic, sedimentation etc.”

Bouffard has been busy over the last eightmonths creating the foundations for the PetroleumConsulting business unit by “putting the peopleand team together and creating the rightenvironment for the team to work under.”

Importantly for Bouffard the new unit will leadto meaningful training and development of the next

generation of geologists and engineers. This newunit will allow Weatherford to provide fulfillingcareer paths for professionals working at thecompany.

“Our ultimate goal is to double our headcountin the next three to four years. We will be able tooffer this service to our employees across ourglobal organisation,” he said.The two key skills that will be emphasized duringtraining will be firstly to encourage and developcreativity and the ability to innovate. The second isthe ability to collaborate and work in a team.

“We are training the new Petroleum Consultingmembers around these two key skills as we believethese are key functions and requirements demandedby our clients. We want our clients to have the bestteam working with them,” Bouffard said.

Petroleum Consulting draws on the combinedstrength of its product portfolio which spans thelife cycle of the well by providing integratedreservoir data solutions, well engineering andproject management, production optimisation andwell abandonment.

Extreme environmentsWhether a client wants to reduce reservoiruncertainty, process data more efficiently or protectthe integrity of their well in any environment the

Petroleum Consulting service through its dedicatedglobal network of geosciences and engineeringprofessionals can provide expert advice on thecritical decisions to maximize recovery inconventional and unconventional reservoirs.

The big advantage of the new service is theflexibility and breadth it can offer. Weatherfordcan tailor their offering to the specific needs ofthe client.

“That is why having this knowledge and globalfootprint can be such a powerful tool offered toclients. We are able to leverage off our experiencesaround the world and give our expert opinion. Webring this knowledge and tools to the client. Theywill better understand their own reservoir andultimately produce more oil,” Kuchinski added.

This can range from Petroleum Consultingproviding advice via Weatherford’s global networkof 38 geosciences laboratories and labs at wellsitethat offer a range of formation evaluation services.Or clients acquiring real-time logging data withLWD technologies that works in the most extremeoperating environments.

SolutionUltimately the new consulting service will enableclients to understand their reservoir better,maximise production and optimise capital spent.

Both Bouffard and Kuchinski emphasised theclient focused nature of the new service.Petroleum Consulting will not only help the clientunderstand their reservoirs better but it will be acollaborative approach whereby feedback from theclients will help Weatherford improve its currentand future capabilities.

“It is really a partnership that we aredeveloping,” Kuchinski pointed out.

There will be Petroleum Consulting teamsdeveloped across all regions that Weatherfordoperates in. According to Bouffard, PetroleumConsulting’s ambition is to make it the preferredtechnical interface between Weatherford and itsclients. “It is to become the arm which understandswhat our clients require on a reservoir standpointand come up with a proper solution for our clients.”

Kuchinski pointed out that the new unit willwork with the client early on in the work flow as itwill it give the client better access to Weatherford’srelevant technologies based on clients’ challengesand drivers.

“The need for knowledge across the industry ispalpable and clients are clamouring for it andPetroleum Consulting will provide the answer,”Bouffard noted.

“We look forward to disseminating ourknowledge to the global client base. The demandcurrently from our clients regarding unconventionalresources is enormous. The hunger to know more isgrowing,” he said.

Bouffard concluded by saying that having juststarted to interface with clients: “we have alreadyhad a very positive feedback. This is veryencouraging. The focus in 2012 is to make this asustainable, long term business.”

Brice Bouffard

Petroleum Consulting brings client collaboration to new heights



AACCORDING TO SUHEIL the evolution of the Digital Oil field (DOF)has been a slow process since being identified years ago due tomany obstacles mainly linked to uniform data exchange platformsand in some cases the limitations of technology used in the oil field.

With the evolution of OPC and other integration platforms and the advancesin hardware and software technology has finally changed all this and DOF hasbecome a reality.

Suheil explained that as DOF requires vast amounts of data from the field innear “real time” for slower and faster loops it was the advances in radiotechnology and abundance of bandwidth and QoS in communications that hasallowed data to be transported with high reliability to the central repositories.

While, advances in hardware platforms whether on the embedded microprocessors or on powerful servers helped quality control data and performrequired analysis in almost real time. Emerging uniform open standardcommunications protocols such as OLE for Process Control, OPC, allowedsystems to share data and exchange data to allow different systems to performdiverse analysis and converge into a needed decision.

“The emergence of all these technologies together is allowing the visionbecome reality and allowing people to execute their own workflows in anautomated process and permitting knowledge and data sharing among differentinterested parties instead of previously having that data compartmentalised insilos,” said Suheil.

OpportunitiesSuheil discussed the opportunities in the DOF arena in the region.

“The Middle East has had it easy over the years except for some particularmarkets, but as awareness of resource optimisation and the capabilities to enhancerecovery from reservoirs and the shortage in qualified resources is pressing oilcompanies to engage the industry in implementations of DOF projects.”

He pointed out that challenges such as water breakthrough and matureassets are imposing the acceleration of need for knowledge sharing, better datamanagement and converting that data into knowledge and smart decisions. Theopportunities 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 tobe doing business. That has dawned on everyone,” added Suheil.

DOF or Smart Oilfields have different levels of smartness and the industryhas been evolving towards DOF through many initiatives, some are throughbasic monitoring and telemetry which has been around for many years, someare going beyond monitoring into remote operations and others are progressingyet further allowing Collaborative Work environments and data/knowledgesharing across their assets and resources.

In the region there are many companies that have been doing a lot ofsmartness for many years such as PDO and Saudi Aramco and others who arepiloting several technologies starting with smart completions up to wellheadthrough the network into processing facilities identifying bottlenecks andoptimising every process along the way.

Wireless impactSuheil 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 DOFenablement and all our acquisitions are around the value loop of the DOF,” saidSuheil. He added: “The solutions we are addressing are to provide oil andservice companies with the components and solutions that will help themrealise the end to end solution or the tools that will allow the user to select the

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, similarlythe company is going at the different elements of the value loop and addressingour products and solutions to complement the need in the market.

Wireless is a major component of these products. “vMonitor has focused onthe upstream market and has differentiated ourselves by carving our own nichefocusing on true upstream applications with the longest range wireless sensorand true wellhead applications.”

vMonitor has also focused on providing the industry the enablers of DOFwith an end to end solution starting with long range wireless sensorsallowing the least amount of gateways in the field with opencommunications protocols reporting to a fit for application SCADA systemwith a flexible polling engine and an integration middleware platform basedon an OPC broker to be able to pass and exchange data with different thirdparty applications and legacy platforms and databases.

“DOF is much more than a trend in theindustry, it is the way we ought to be doing

business. That has dawned on everyone“

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Sami Suheil, CEO of Monitor, talked to Oil Review about the growth in digital oil fieldsin the region and how vMonitor’s wireless solutions are the best fit for these markets.

Growth of

digital oil fields

Sami Suheil, CEO of Monitor

S17 ORME 3 2012 IT_Layout 1 05/04/2012 15:07 Page 88

InnovationSuheil talked about new product launches plannedfor later this year, including products that willcomply with the emerging standards and othersthat address applications using our product line andadding some local intelligence on the producttaking advantages of the advances inmicroprocessor capabilities.

vMonitor launched a few products last yearamongst which is an orifice based single Phaseflow computer that uses some petroleumengineering correlations, some PVT data and a welltest for calibration to estimate the multiphase flow.It is a great tool for doing allocation in real timeversus using the well test to do allocation for thewell over the period between well tests.

“Our methodology in this product and otherproducts and solutions we have on the drawing boardis to go by the 80/20 ratio, providing the industrywith a solution that can address 80 per cent of thefunctionality for 20 per cent of the cost,”said Suheil.

ProjectsvMonitor has been awarded several big projectsover the last year mainly in Kuwait, Venezuela, andother markets where mass commercial roll outs arebeing considered with the client.

“Kuwait is a tremendous market and a reallyexciting market.”

KOC has a wide range of reservoirs and have alltypes of crudes and production. On top of that KOCis really adopting the holistic approach to DOF andis starting from the grounds up by collecting datafrom all brown fields, providing their users access tothat data and allowing different vendors tohighlight their technologies by analysing that dataand recommending solutions to better optimisethe process and enhance recovery.

“KOC is trying to implement a vendoragnostic approach to the process of operatingand managing their assets,” he added.

Suheil gave his outlook for the industry in 2012saying: “It is promising to be another good year fordemand and a momentum building year withglobal market health indicators leading to moreautomation and implementation of DOF throughout several organisations, the instability in theregion in particular and Europe’s economic troublescan have an impact on the demand side of theequation due to supply routes and higher prices.” n


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vMonitor products in action on a ADMA-OPCOinstallation just off the Abu Dhabi Coast (Zakum Field)

“Our whole product lineand growth strategyis cantered around

the DOF enablement and all our acquisitions

are around the value loop of the DOF”


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SCHLUMBERGER HAS LAUNCHED MicroScope 475, which is a high-resolution resistivity and imaging-while-drilling service.On a single collar, this logging-while-drilling service provides high-resolution laterolog resistivity and full borehole images inconductive mud environments. The technology provides keyinformation for formation evaluation, well placement and fractureidentification.The MicroScope tool acquires focused laterolog resistivitymeasurements and images at four different depths of investigationwith azimuthal sensitivity. These measurements are essential forcalculating reserve estimates, placing horizontal wells andoptimisingcompletion design."Optimal placementof the borehole inthe reservoir,accurate evaluationof formationproperties andidentification ofgeological featuresthat 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 ithas being tested rigorously and deployed worldwide. The serviceaddresses challenges in unconventional shale plays, carbonate andclastic reservoirs. The majority of the testing took place in thecarbonate projects in the region.

EMERSON PROCESS MANAGEMENT introduced an EtherNet/IP Module forMicro Motion Coriolis meters. Suitable for new or retrofit installations, themodule is compatible with all Micro Motion Coriolis flowmeters, and is suitablefor hazardous areas. Access to the multivariable data enabled by the module allows for increasedproductivity 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 Modulecan be mounted in the control cabinet, removing the need to run Ethernetcabling out to the field. The module web browser provides network access toa powerful configuration and diagnostic interface, enabling a full range ofremote activities. This includes running Smart Meter Verification, whichdetermines Coriolis meter performance without stopping the process orinterrupting the flow.The module enables quick and cost effective access to the growingnumber of EtherNet/IP plant-wide networks and adds to the range ofcommunication interface options available with Micro Motion Coriolisflowmeters. These include DeviceNet, PROFIBUS DP, Modbus,FOUNDATION fieldbus, and PROFIBUS PA in addition to the traditionalinterfaces of 4-20 mA frequency and HART.The EtherNet/IP Module is suitable for DIN Rail mounting and is ODVACertified. The software provided enables Micro Motion Coriolis flowmeters to beeasily configured remotely via the plant network.Ethernet/IP is an open, industry-standard networking technology supportingconnections to a wide range of devices including motor starters, sensors,controllers and HMI devices. Ethernet/IP supports non-industrial and industrialcommunications on a common network infrastructure.

MicroScopebeing installed

IN AN EXCLUSIVE interview with Oil Review Middle East, Odd Hjelmeland,CEO of Norway’s Numerical Rocks, and Victor Pantano, CEO of Australia’sDigitalcore, spoke about their decision to merge the companies and create aglobal leader in the field of digital rock analysis.

“I was previously CEO of the ResLab Group so I know all aboutcharacterising core material conventionally” explained Hjelmeland. “It cantake a long time to run complex experiments. I believe that digitaltechniques will complement physical experiments and give morepossibilities for sensitivity analysis or what-if-scenarios. Numerical Rocks hasspent eight years perfecting the process. Our e-Core™ software importsimages or a detailed description of the rock sample and, using knowledge ofgeology and reservoirs, we can accurately predict rock properties and fluidflow characteristics.”

“Digitalcore has been focussed on providing the best possible images“said Pantano. “In more than ten years of research at the Australian NationalUniversity, we have found that the only way to get the image quality weneed in a timely manner is to build bespoke micro-CT scanners incorporatingunique capabilities such as out HeliScan™ helical scanning technology.Equally important, we can combine 2D and 3D images at various resolutionsusing our VoxelPerfect™ software to further improve the rock model.”

Odd explained the drivers behind the merger. “While the opportunitiesare immense, each of us is located on the fringes of the international oil andgas business – we in northern Norway and Digitalcore in southern Australia.Most of our prospective clients are locations in the Middle East, theAmericas, Europe and in southern Asia. We want to bring a local presence tothese 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 significantinflux of additional capital which will fund our growth, especially in theMiddle East and the Americas. Our intention is to have a fully commerciallaboratory running in the Middle East within one year.”

“This is a service business, so despite the advanced technology andsoftware, the goal is to provide a faster and more standardised set of clientservices that are delivered on time and offer incomparable value-for-money”added Pantano. “We will still undertake specialist projects, where we areworking on the boundary of current technology. There are lots of challenges,such as developing a better understanding of wettability and how it variesthroughout the reservoir. Digitalcore has been making great advances in thisarea and we are all excited to see how those will result in an even moreaccurate 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 manyyears of industry experience, and an in-depth understanding of the issues andchallenges of accurately imaging and modelling reservoir rocks. The mainchallenge will be in establishing overseas laboratories, training newtechnicians and analysts, and continuing to provide a quality service basedon speed, accuracy and complete data transparency.”


EtherNet/IP module added to flowmeters Digitalcore and Numerical Rocks merge

Imaging-while-drilling technologylaunched by Schlumberger

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Dr. Odd Hjelmeland and Dr. Victor Pantano shake handsafter the merger announcement.


THE 4TH SAUDI ARABIA INTERNATIONALOIL & GAS EXHIBITION

24-26 SEPTEMBER 2012DAMMAM, KINGDOM OF SAUDI ARABIA

WWW.SAOGE.ORG



Middle East & North African Rig Count

THIS MONTH VARIANCE LAST MONTH LAST YEAR

Country Oil Gas Misc Total Oil Gas Misc Oil Gas Misc Total

Middle EastABU DHABI 19 2 0 21 1 0 0 18 2 0 20

BAHRAIN (1) 4 0 0 4 0 0 0 4 0 0 4

CYPRUS (1) 0 0 0 0 0 -1 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

KUWAIT 25 6 0 31 -2 1 0 27 5 0 32

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

YEMEN 2 0 0 2 0 0 0 2 0 0 2

TOTAL 173 65 0 238 -5 3 -1 177 62 1 240

North AfricaALGERIA (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

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.

Source: Baker Hughes


S18 ORME 3 2012 Arabic_Layout 1 05/04/2012 15:53 Page 93

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12–14 June 2012BMO Centre // Calgary, Alberta, Canada

www.spe.org/events/ihoc

www.spe.org

Society of Petroleum Engineers

Held in conjunction with

Discover global best practices and technologies in heavy oil exploration and production at this inaugural event


5 - 8June 2012

Baku • Azerbaijan

www.caspianoil-gas.com

LEADINGOIL & GAS EVENTIN CASPIAN REGION

19th International

CASPIAN OIL & GASExhibition and Conference

Refining & PetrochemicalsIncorporating

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

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China Wang Ying (86)10 8472 1899 (86) 10 8472 1900 [email protected] Tanmay Mishra (91) 80 65684483 (91) 80 40600791 [email protected] Camilla Capece (39) 06 97619380 [email protected] Bola Olowo (234) 8034349299 [email protected] Sergei Salov (7495) 540 7564 (7495) 540 7565 [email protected] Africa Annabel Marx (27) 218519017 (27) 46 624 5931 [email protected] Saida Hamad (974) 55745780 [email protected] UK Steve Thomas (44) 20 7834 7676 (44) 20 79730076 [email protected] Michael Tomashefsky (1) 203 226 2882 (1) 203 226 7447 [email protected]

GCNÑ````ÉQ

J≤ÉQjô NÉU°á: T°ôcá Jæª«á fØ§ YªÉ¿, GEjôG¿, Hëô bõhjø.

J≤æ«Éä:J≤æ«á Gd¨ÉR Gd£Ñ«©» GŸù°É∫, Gdàμôjô hGdÑÎhc«ªÉhjÉä.

J≤ÉQjô aæ«á:J≤æ«á Gdàμù°Ò, WÓAGä G’CS°£í, J≤æ«á G◊≤ƒ∫ GdÑëôjá.

JμæƒdƒL«É GŸ©∏ƒeÉä hG’Jü°É’ä:GŸôGbÑá Yø H©ó, GCeø GŸ©∏ƒeÉä.

e©ÉQV¢:GdæØ§ hGd¨ÉR ‘ ZôÜ GBS°«É.

–∏«```Óä4

01 –∏«```Óä01

Company ................................................PageAban 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

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 – 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

ADVERTISERS INDEX


China Wang Ying (86)10 8472 1899 (86) 10 8472 1900 [email protected]

India Tanmay Mishra (91) 80 65684483 (91) 80 40600791 [email protected]

Italy Camilla Capece (39) 06 97619380 [email protected]

Nigeria Bola Olowo (234) 8034349299 [email protected]

Russia Sergei Salov (7495) 540 7564 (7495) 540 7565 [email protected]

South Africa Annabel Marx (27) 218519017 (27) 46 624 5931 [email protected]

Qatar Saida Hamad (974) 55745780 [email protected]

UK Steve Thomas (44) 20 7834 7676 (44) 20 79730076 [email protected]

USA Michael Tomashefsky (1) 203 226 2882 (1) 203 226 7447 [email protected]




Documents

Oil Review Middle East issue 3 2012