ORME 7 2013 COVER_ORMETHREE05COVER.qxd 01/11/2013 16:01 Page 1
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VOLUME 16 | ISSUE 7 2013
Covering Oil, Gas and Hydrocarbon Processing UK £10, USA $16.50
ADNOC - rising to the production challenge
Abu Dhabi sour gas: same difficulties, new possibilities Delivering Iraq’s oil boom The need for next generation seismic The cost of corrosion Effective metering solutions Communications - from the wellhead to the rooftop
“All sources of energy - with oil and gas at the core - will be needed to meet global energy demand.” Khalid. A. Al-Falih, president & CEO, Saudi Aramco See page 134
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Editor’s note ABU DHABI’S DYNAMIC oil and gas sector continues to thrive. At it’s heart is the stateowned oil firm, Abu Dhabi National Oil Company (ADNOC), which has a stake in almost all corners of the industry, both upstream and downstream, via it’s multiple subsidiaries. Oil production is riding high and expected to grow further in the years to come, with investment soaring. Abu Dhabi’s planned production hike is expected to come from a range of new and existing oilfields, both onshore and offshore. Once again, ADNOC companies will play a central role in making this happen, in conjunction with foreign partners. The heavy spending of recent times - and the award of numerous multi-billion dollar contracts - has excited international engineering firms and contractors, many of whom will be at ADIPEC. As well as racing to supply its own needs, Abu Dhabi is also responding to the changing global energy market, focusing more of its attention on the high-growth Asian markets.
Contents
8
Industry news and executive’s calendar
143 Corrosion Prevention
Analysis
148 Integrity Management Reducing hydrocarbon releases.
152 Industrial Footwear Timberland has plans for regional growth.
Developments
156 Pipeline Technology
Gas
Redefining oil pipeline coating.
Analysis
158 Metering Expro sees increased metering demand.
Petrochemicals & Refining 49
162 Offshore Technology
News
Temporary high-end accommodation.
Country Focus 57
Communications & IT
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Iraq Capitalising on Iraq’s gas potential.
© Oil Review Middle East ISSN: 1464-9314
171 Wireless Technology BP benefits from free space optics.
Conferences & Exhibitions
176 Seismic Technology
Basra Oil and Gas
The need for next-generation seismic.
Investors and suppliers are welcome.
67
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164 Innovations
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Surface coatings minimise corrosion.
Exploration & Production
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Technology
28
Managing Editor: David Clancy
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Columns
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Serving the world of business
180 Rig Count/Project Databank
ADIPEC Delegates set to converge on Abu Dhabi.
141 SAOGE A key energy-business event is back.
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Arabic Section 4
News
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Saudi Arabia
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Kuwait
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CALENDAR
Executives Calendar 2013/2014 NOVEMBER 2013 10-13
Adipec 2013
ABU DHABI
www.adipec.com
11-14
Rockwell Automation's Automation Fair
HOUSTON
www.rockwellautomation.com
25-27
SAOGE
DHAHRAN
www.saoge.org
BASRA
www.basraoilgas.com
DECEMBER 2013 5-8
Basra International Oil & Gas Exhibition
JANUARY 2014 19-22
ITPC 2014
DOHA
www.itpcnet.org
20-22
World Future Energy Summit
ABU DHABI
www.worldfutureenergysummit.com
AL KHOBAR
www.petroenvironment.com
FEBRUARY 2014 24-26
Petro Environment
MARCH 2014 1-3
Saudi Safety and Security
DHAHRAN
www.sss-arabia.com
9-12
Middle East Downstream Week
ABU DHABI
www.wraconferences.com
9-12
Petchem Arabia 2014
ABU DHABI
www.wraconferences.com
Readers should verify dates and location with sponsoring organisations, as this information is sometimes subject to change.
Report predicts strong growth in Middle East oil market THE GLOBAL OIL demand continues to rise, while the oil industry is increasingly using alternative oil sources such as heavy oil, according to the recently published Heavy Oil Market 2013-2023 report. The heavy oil market is expected to play a crucial role in global crude supply in the future. Soaring oil prices and innovative technology are making an increasing
number of heavy oil projects commercially viable, which is creating opportunities for various companies within the oil sector. According to business information provider, Visiongain, the global heavy oil market will see output reach 6.6mn bpd in 2013. This also includes heavy/extra-heavy oil operations outside the Middle East, such as Canada and Venezuela. Visiongain, however stated that this did
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Issue 7 2013
not include oil sands projects where bitumen is the primary target. The majority of heavy oil projects have taken place in the Western Hemisphere. The report also revealed that less developed regions, such as the Middle East are expected to report strong growth in the oil sector, as countries aim to utilise their substantial heavy oil reserves over the next decade.
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News
Libya’s oil and gas industry faces uncertain future, claims analyst
Halliburton reveals 17 per cent rise in profit
LIBYA’S OIL AND gas industry continues to be unpredictable, with current output levels remaining low, according to an analyst with research and consulting firm GlobalData. Will Scargill, an analyst covering upstream oil and gas in the MENA region, said economic, political and social divisions, combined with an unstable security environment, are stifling the oil industry when the country needs it the most. Additionally, labour strikes and disagreements between different social and political groups have shut down oil production and export, he claimed. The El Sharara oil field, Libya Libya does however remain the source of more than 10 per cent of production for IOCs such as Eni, Scargill claimed that Libya’s political Repsol, Marathon Oil Company and OMV, divisions may have long-lasting effects on said Scargill. the oil and gas industry, as the country Operations also recovered quickly moves to create a new exploration and following the 2011 conflict, although recent production sharing agreement (EPSA-V) to disruptions at oil export terminals have attract investment. reduced output to as low as 230,000 bpd in Such divisions, and the lack of a September 2013, Scargill said. By October, constitution, place roadblocks for the production stood at around 600,000 bpd – legislation required, which means that a new well below the 2012 levels of 1.4mn bopd, licensing round could be further delayed, he said. possibly into 2015, he said. “European IOCs have invested The round was originally proposed for late significantly in their Libyan holdings and are 2013, and the most recent date scheduled keen on monetising their investment. was early 2014. However, in a sign of losing patience, “This will disappoint both the Libyan Marathon has signalled that it is considering government, which needs to reignite its core selling its share,” Scargill said. industry and attract investment, and the “In addition, BP has yet to resume IOCs, which are expecting the EPSA-V to activity on its three exploration blocks in the offer improved terms on a large resource country,” he added. pool close to home,” concluded Scargill.
BUOYANT OILFIELD ACTIVITY in Saudi Arabia, Angola and Russia has helped Halliburton beat market expectations with a 17 per cent rise in profit, according to the company. Halliburton chief executive Dave Lesar said, “Our eastern hemisphere growth continues to lead our peer group. Consistent with prior years, we expect the fourth quarter in the eastern hemisphere to be our strongest quarter of the year, due to seasonal year-end software and equipment sales.” The company’s Q3 net profit rose to US$706mn (US$0.79 per share) in 2013 from US$602mn (US$0.65 per share) at the same time in 2012, with revenue rising five per cent to US$7.47bn, Halliburton said. Excluding restructuring charges, the company reported earnings of US$0.83 per share, a penny above what analysts had expected on average, according to Reuters. Schlumberger and Baker Hughes have also posted higher than expected earnings recently, reportedly boosted by offshore drilling and activity outside of North America. Baker Hughes said it expects its rig count in the USA to average 1,750 rigs for 2013, which is down nine per cent from 2012. The company said however that the industry is drilling approximately six per cent more wells per rig in the country. On the other hand, the international count was expected to average 1,300 rigs in 2013, up five per cent from last year, Baker Hughes said.
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Analysis
Delivering Iraq’s
oil boom
Nicholas Newman looks at the technical challenges and achievements made by the various contractors including Leighton Offshore in delivering Iraq’s crude oil export expansion project. Together with its implications for Iraq’s ability to increase its exports to the rest of the world.
Basra’s oil export facilities are being upgraded
D
ESPITE MANY YEARS of sanctions and war, the Iraqi energy sector is booming. This is due in part, to the massive on-going investments made by international oil companies in restoring and developing Iraqi oil and gas fields and, in part, to the multi-million Iraq Crude Oil Export Expansion Project designed to increase Southern Iraq’s export capacity from 1.8mn barrels a day (bpd) to 4.5mn bpd by 2014. According to the latest BP data, Iraq has proven oil reserves of 141bn barrels, the fifth largest proven crude oil reserves in the world after Saudi Arabia, Venezuela, Canada and Iran. 12
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In 2012, Iraq surpassed Iran as the second largest producer of crude oil in OPEC. Last year, Iraq exported 2.4bn barrels of crude oil and was the sixth largest net exporter of petroleum liquid in the world, the majority of oil exports going to refiners in the US, India, China and South Korea.
Questionable
In 2012, Iraqi crude oil production averaged around three million bpd which is planned to increase to 10mn bpd by 2017. However, such an expansion will require a huge investment in power infrastructure alongside investment in seawater or natural gas injection to
maintain oil reserve pressure in Iraq’s southern oilfields. Whether the requisite investment will be forthcoming is questionable given that the proposed Hydrocarbon Law of 2008, which will govern the development of energy assets, has still not been passed. Moreover, the negotiating stance adopted by Iraq’s government with oil and gas companies is not auspicious. Iraq’s oil fields are located in the Kurdistan Region of Iraq in the north and in the south, which alone, accounts for 60 per cent of the country’s proven oil reserves and three quarters of crude oil production. The existing export pipeline corridors,
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Analysis
through Syria, Turkey and Saudi Arabia are proving insufficient to the task of rising Iraqi oil output. The solution, as envisaged by the US Corp of Engineers and accepted by the Iraq Ministry of Oil, was to refurbish, enhance and construct new export facilities at Fao and Basra linked to four new offshore offloading platforms, each with a capacity of 900,000 bpd suitable for receiving and loading Very Large Crude Carrier Tankers (VLCCs).
Largest
The Iraqi Crude Oil Export Expansion Project (ICOEEP) will create one of the world’s largest offshore oil loading facilities and is being constructed in three phases. Construction in Phase 1, costing some US$733mn began in February 2011 with the first oil cargo reaching the oil tanker, Maersk Hirado in April 2012 and completion of works in November 2012. Phase 1 involved the commissioning and installation of two 140-km parallel pipelines, each 48” in diameter. Contractors laid a pipeline network linking the onshore Foa Terminal with the ABOT offshore oil loading facility in the Gulf, some 120-km offshore. Where the pipelines met the seashore, contractors have constructed a beach valve station.
Dredging
Offshore, three Single Point Mooring systems capable of loading VLCC tankers were installed. On the seabed, a 600MT Subsea Manifold was constructed and fitted to connect the fixed pipelines delivering oil from
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Existing facilities are insufficient to meet demand the shore to the flexible pipes that deliver oil to tankers. The project also involved dredging to create trenches to bury the pipelines between the shore and the facility, together with increasing the depth of the seabed to allow access by PANAMAX Plus tankers to the site when full. Onshore, the project involved the construction and commissioning of new facilities at the Fao terminal where sixteen new crude oil storage tanks, each with a capacity of 350 kbbl (56,000 m3), were brought online. These 16 storage tanks, represent 25 per cent of the 64 tanks planned. The first phase also included the installation of telecoms and SCADA (supervisory control and data acquisition)
systems together with training personnel . Phase 2 consists of a further expansion of the country’s oil export capacity from 2.2mn to 4.5mn bpd in early 2013. Japan International Cooperation agency is a major investor in the scheme. The scope of work involved in Phase 2 includes the laying of a 48-inch, 72-km long pipeline between the onshore tank farm and pumping station at Fao and the two Gulf terminals and installation of valves, tie-ins, manifolds and control systems.
Capacity
A Single Point Mooring (SPM) is to be installed near Basra and connected by a sea line to valve stations at the Gulf terminals. Phase 2, costing some US$500mn, due for completion at the end of 2013, adds a new central metering and manifold platform and brings three SPMs online and sees the installation of a fourth. Phase 3 will see the construction of 10km of onshore pipeline that will connect the inland oil storage facilities with the offshore shipping terminals. It will also include the installation of 45-km of trunk line and a single SPM and is expected to be operational in 2014. Once fully complete, there will be 64 storage tanks and four terminals, each with the capacity to load onto super tankers with the maximum draft of 21 m, 850,000 bpd, adding 3.4mn barrels of export capacity – a major contribution towards the Iraqi government’s ambitious plan to double the country’s oil production by 2015. The contract for the scheme was awarded by Iraq’s state owned National South Oil Company (SOC) to British owned engineering consultancy Foster Wheeler to provide project management services that included front-end engineering and design. Foster Wheeler's scope of work included monitoring and administering the purchase orders and contracts that have been placed
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Analysis
by SOC in accordance with the recommendations made by Foster Wheeler during the execution of the basic engineering contract for this investment. “Foster Wheeler is delighted to have been involved in this strategically important project since its inception in 2007,” said Umberto della Sala, President and Chief Operating Officer. Australian owned Leighton Offshore won the engineering, procurement and construction contracts for Phase 1 and 3 of this transformative scheme. “We are very proud of our record of safety operating and maintaining one of the world’s largest export terminals here in Iraq, after the successful installation by Leighton of the pipelines and SPM systems”, Leighton Offshore, CEO, Boyd Merrett said Leighton worked with Australian asset management firm K2 Technology, to supply the resources for building the computerised maintenance management system for Phase 1.
Project support
In addition, Leighton Offshore worked with Hong Kong- based BEKK Solutions, which provided diving support for subsea installation works during Phase 1. For dredging, Leighton used Dutch- based Van Oord to dredge a 43-km-long trench and turning basins around three oil loading buoys. The project site is located at the mouth of the river Euphrates. Van Oord used its largest trailing suction hopper dredger HAM 318 and two cutter suction dredgers. The HAM 318 worked at a distance of approximately 40-km offshore. The cutter suction dredgers were used working closer to the coast. During project execution, all employees for their safety remained offshore. Italy’s Saipem, was awarded the Phase 2 engineering, procurement and construction contract, which was worth in October 2011 some US$1.5 billion. Saipem’s contract encompassed the engineering,
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Security of men and equipment has been a major consideration procurement, fabrication and installation of a Central Metering and Manifold Platform (CMMP), installed at a water depth of 28 metres, along with associated facilities. Lastly, the British oil field services company, Petrofac was awarded a US$100mn contract in August 2012 to provide offshore operations and maintenance services for the project for a 12-month period.
Obstacles
This civil engineering scheme is notable for its timeframe from conception in 2007 with feasibility studies, commissioning, installation and construction being completed in 2014. Security of men and equipment was a major consideration alongside the clearing of unexploded ordnance. Generally, contractors have had to recruit and bring in their staff and supplies from outside Iraq. The dredging of a canal of 3.5-km in length and 70 metres in breadth at a depth of 5.25 metres at low tide created 13m.m³ of spoil which had to be removed from the site. The soil in the Al Fao area has a
consistency not unlike toothpaste and required a great deal of piling work. Transport difficulties, political disputes, bureaucracy, corruption, unfavourable weather and freight delays were additional obstacles to overcome. The post war reconstruction of Iraq’s oil sector and its export facilities under the Iraq Crude Oil Export Expansion Project will allow the country to reach its production potential and ensure the transformation of Iraq into an ‘Energy Powerhouse’ (IEA). However, this export corridor is vulnerable in any conflict with its neighbour or if the Straits of Hormuz become blocked. It is clear that Iraq is well on its way to becoming a major oil exporter, with the construction of such an impressive project which will allow southern oil fields to climb towards their production potential. However, this export corridor is vulnerable, if there is any conflict with its neighbour, Iran or if the Straits of Hormuz are blocked in some future dispute between the US and Iran. ■
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Analysis
Abu Dhabi sour gas: challenges
and possibilities
The coming year sees the beginning of what could be a new era for gas production. Sour gas reserves previously considered too technically challenging to process safely and reliably will produce usable gas. But developing the Shah Arab sour gas reservoir has meant overcoming a number of challenges for Abu Dhabi Gas Development Company Ltd (Al Hosn Gas) and its partners in the project. David Schulte, Curt Graham, Thomas Chow, Fluor Energy & Chemicals*
A
BU DHABI GAS Development Company Ltd - Al Hosn Gas - is nearing completion of the multibillion dollar programme to develop the Shah Arab sour gas reservoir. The Shah Gas Development (SGD) project, which is scheduled for start-up in 2014, is a significant part of Abu Dhabi’s plan to meet its growing domestic needs. The new SGD facilities are designed to process approximately one billion standard cubic feet per day (BSCFD) of well fluid containing 23 per cent hydrogen sulphide (H2S). From this feed gas stream, the project will provide 500mn standard cubic feet per day (MMSCFD) of clean natural gas for the Abu Dhabi market. But that is far from all. It will also supply 4,400 tons per day of natural gas liquids, 35,000 barrels per day of condensate, and 9,200 tons per day of elemental sulphur for industrial and agricultural markets. These figures would be impressive for any project. However, the SGD project was unusually demanding. The very high H2S and organic sulphur content of the well fluid and the extreme site conditions either impacted the design of the process units or required the addition of specialised process systems and technologies. Not only that, but key health, safety, and environment (HSE) features had to be developed during the design stage of the project to ensure that the very sour gas could be safely processed. In fact the reserves of this reservoir were once considered too technically challenging to process safely and reliably. Nevertheless any challenges have been, or are being, overcome. But before we discuss how this is being done, we need to go back to the beginning - starting with the location of the site. The SGD facilities are approximately 180km southwest of Abu Dhabi city. The 18
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Project Overview Shah Processing Plant Separation & Stabilisation
Slug Catcher Well Fluid
Sour Condensate Utilities & Offsites
Sour Gas
Hydrotreater
Acid Gas Removal
Dehydration NGL Recovery
Sales Gas
Acid Gas NGL Sulphur Recovery
Sulphur
Condensate
System Slug Catcher
Train Size
Number of Trains
1,000 MMscfd
2 x 100%
Inlet Separation & Stabilisation
500 MMscfd
2 x 50%
Acid Gas Removal
250 MMscfd
4 x 25%
Dehydration & NGL Recovery
330 MMscfd
2 x 50%
Sulphur Recovery Hydrotreating
2,500 TPD
4 x 25%
25,000 BPD
2 x 50%
15
Figure 1: Overall block flow diagram – Shah Processing Plant topography of the Shah area is dominated by large sand dunes with elevation differences exceeding 100 m. The footprint of the processing facility will cover an area of about 5.4 km2. The SGD project consists of four main elements: a gas gathering system; the Shah processing plant; product pipelines; and the Shah sulphur station. Each of these is worth examining in closer detail. Gas gathering is a case in point. The Shah Arab Field is a large anticline reservoir with approximate dimensions of 30km by 5km. It was discovered in 1966, but has never been in production - until now. The maximum gas production rate for the Shah Field is 1,000
MMSCFD, referenced at the inlet of the acid gas removal units within the Shah processing plant after removal of produced water and condensate. The gas gathering system design is based on a minimum wellhead flowing pressure of 97 barg and a minimum delivery pressure of 69 barg at the Shah processing plant. The field is expected to be at maximum production for over 20 years. The design life for the gas gathering system and pipelines is 30 years. As for the Shah processing plant, an overall block flow diagram (Figure 1) highlights the connectivity of the process units and the size of the trains. The established operation and maintenance
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Analysis
philosophies and the target availability required the process units to be configured in two 50 per cent trains. Some units were exceptions to this philosophy due to equipment size and transportation constraints. Next we come to the product pipelines. In fact four new product pipeline systems are needed to support the Shah processing plant. The first of these is a 36-inch (914.4mm) gas pipeline that ties in to an existing sales gas network. The total length of the gas pipeline is 128km. A 16-inch (406.4mm) NGL pipeline (total length 66km) ties in to an existing pipeline network, as does a 16-inch condensate pipeline (again 66km). Two short sulphur pipelines make up the rest of the system. They use a system called skin-effect electric tracing (SEET) and are routed to the Shah Sulphur Station located nearby. Two 100 per cent sulphur pipelines are provided to ensure reliable delivery of liquid sulphur to the station. The final element of the four that make up the SGD project is the Shah sulphur station, approximately 5km north of the Shah plant. This is a stand-alone facility designed to process a total of 10,000 TPD (tons per day) of liquid sulphur received from the Shah plant. The sulphur is granulated and loaded on to rail cars for transportation to the Ruwais Industrial Area. Impressive as the aims of the project are - and the elements supporting it - equally noteworthy is the aggressive pace at which it has moved forward. This has been driven by the urgent need for sales gas in the UAE. Thus, despite its size, cost, and complexity, the SGHD project quickly hit a number of key milestones:
Figure 2: Construction site at Shah
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The SGD project is a significant part of Abu Dhabi’s plan to meet growing domestic requirements • June 2007: feasibility studies and conceptual design completed • February 2009: front-end engineering and design (FEED) completed • March 2010: early works package awarded • May 2010: main Shah engineering, procurement, and construction packages awarded • February 2011: well drilling starts • Q3 2014: performance testing complete Fluor Energy & Chemicals, the division of Fluor Corporation that takes its engineering, procurement, construction, maintenance and project management services into the energy and chemicals industries, plays a major part in this project. Its roles and responsibilities include: feasibility studies and conceptual design; FEED; technology licensor; and project management
consultancy (PMC) services during the engineering, procurement and construction (EPC) phase But design, technology and project management are not the whole story, by any means. Designing the Shah plant for a feed rate of 1,000 MMSCFD of well fluid containing 23 per cent H2S, 10 per cent CO2, and high levels of organic sulphur contaminants presented three main challenges. The first was HSE. Al Hosn Gas has an important responsibility to protect staff, contractors, local communities, and the natural environment. There were major hazards associated with the high pressure, very sour feed stream. In addition the remoteness of the site location, the topography of the site location, and the scale of the facility presented logistical problems. Process design was also a challenge because of the unique feed gas composition, the tight product specifications, stringent emissions limits, high reliability and efficiency targets, and the hostile desert environment. All of these challenges were addressed during the course of the development of the design by Fluor, as is explained below, and in more detail in the material referenced at the end of this article. As shown in Figure 2, the topography of the Shah area makes construction very challenging. To minimise the extent of the required earthworks and the impact on the native desert, a decision was made during the FEED phase to situate the main plant in three large, connected sabkhas (salt flats). The next step was to determine how best to utilise the three sabkhas. This meant separating the plant facilities into groups based on their process functions and risks. For emergency escape planning, it was then necessary to define the boundary of the restricted area within which a worker would not be able to respond to a sudden loss of containment. These areas contain the high
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Analysis
pressure, very sour gas handling equipment (housed in a ‘red zone’). In addition to meeting the requirement to produce premium sales gas, NGL, condensate, and sulphur product streams, the technologies selected for the Shah Plant had to be reliable, flexible, commercially proven, and energy efficient. Process optimisation was a major area of focus during the Pre-FEED and FEED stages of the project. The plant relies heavily on licensed technology for the key units. Take the acid gas removal units (AGRUs), for example. The purpose of the AGRU section is to remove H2S and COS from the sour feed gas stream to produce sweet gas that is suitable for sales gas after further processing in the gas dehydration and NGL recovery units. Since the NGL recovery units are designed for very high ethane recovery (94 per cent+) and operate at very low cryogenic temperatures, bulk CO2 removal is also required in the AGRUs to prevent CO2 freezing. The acid gas from the solvent regenerators is sent to the sulphur recovery units for conversion of the H2S into elemental sulphur. Fluor’s licensed process using an aqueous diglycolamine (DGA) solution was selected for the AGRU trains due to its ability to remove COS without the need for a separate COS hydrolysis step. DGA is particularly suited for desert environments because it can easily achieve the tight H2S sales gas specification at high operating temperatures. The effectiveness of DGA has been proven on a large scale in other similar locations. Turning next to NGL recovery, two modes of operation are required for the SGD NGL recovery units: ethane recovery and ethane rejection. In the ethane rejection mode, the NGL recovery plants are operated such that ethane is rejected with the residue gas. The units are capable of operating at ethane recovery levels between two per cent and 94 per cent while maintaining propane and butane recovery over 99 per cent. The NGL recovery units utilise a very efficient licensed design provided by Ortloff, a leading name in cryogenic gas liquids recovery, LNG processing, sulphur recovery, and sour gas processing plant design. This process minimises compression power and provides excellent propane and heavier hydrocarbon component recovery while allowing ethane recovery to be easily varied between two per cent and 94 per cent with minimal operational changes. Regeneration gas purification is another requirement of the project. The regeneration gas leaving the molecular sieves in the gas dehydration/desulphurisation area during the heating step is not suitable for use as fuel gas due to high sulphur content. Also, it cannot be blended into the sales gas
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The plant relies heavily on licensed technology for the key units product due to the tight quality specification. Consequently, a purification step is required. The regeneration gas from the adsorbers is cooled, compressed, and sent to the regeneration gas purification unit. The regeneration gas purification unit removes desorbed mercaptans (a sulphur-containing organic compound; general formula RSH) using a proprietary physical solvent. The selected licensed process provided by UOP, a leading international supplier and licensor for the petroleum refining, gas processing, petrochemical production and major manufacturing industries, will produce a treated gas containing very low levels of total sulphur (organic sulphur + H2S). The mercaptans and H2S stripped from the solvent in the regenerator are routed to the sulphur recovery units. Condensate hydrotreating is another requirement for which technology selection was important. The function of the condensate hydrotreater (CHT) units is to remove organic and elemental sulphur compounds from the condensate. The quantity of condensate is expected to vary during the life of the SGD project. A generous margin was included in the design of the hydrotreaters to account for uncertainties in the well fluid composition, and to ensure that the liquid handling capacity of the plant does not become a bottleneck for plant throughput. Finally we turn to technology selection for sulphur recovery. Fluor’s licensed twostage Claus plant with hydrogenation/amine tail gas treating was selected in order to meet the emission requirement of 500 mg/Nm3 SO2 in the incinerator stack gas (corresponding to over 99.9 per cent overall sulphur recovery). A licensed process is also used to degas the liquid sulphur from the sulphur condensers to reduce residual H2S from about 300 parts per million weight (ppmw) to less than 10 ppmw. A proprietary solvent was selected for
use in the amine section of the tail gas treating units based on its significant savings in capital and operating costs compared to other solvents. The sulphur recovery unit and tail gas treating unit (SRU/TGTU) complex is heavily integrated with the overall Shah utility system design. Waste heat from the Claus thermal stages and the incinerator is recovered and used to generate highpressure (HP) superheated steam for electric power generation. Sour water produced in the TGTUs is treated and used as boiler feed water makeup for the facility. These design provisions significantly increase the energy efficiency of the Shah Plant. That, in brief, is the systematic design approach used for the SGD project. It will enable Al Hosn Gas to achieve its main objectives of world-class HSE performance and reliable production of sales gas. But it will, it is hoped, do even more: Al Hosn Gas intends to become a world leader in the development of sour gas resources and deliver a project that will set a standard of excellence. ■
References/further reading [1] Almuhairi, A., Kassamali, N., Schulte, D., Graham, C., Nielsen, D., “The Shah Gas Development Project – A New Benchmark” SOGAT Conference, Abu Dhabi, U.A.E., 2009. [2] Madkour, S., Elkins, M., Chow, T., Wong, V., “10,000 MTD Sulfur Recovery and Tail Gas Treating Complex for the GASCO Shah Gas Development Project,” SOGAT Conference, Abu Dhabi, U.A.E., 2009. [3] Almuhairi, A., Sahoo, T., Ross, I., Schulte, D., Mangas, R., “The Shah Gas Development Project – A Systematic HSE Approach to Sour Gas Processing,” SOGAT Conference, Abu Dhabi, U.A.E., 2011.
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Analysis Is the regional downstream industry in danger of complacency? Chris Hotblack, director, HPI & Modernisation Consulting, EMEA at Invensys advises caution.
Producers must focus on
continued excellence O NE CAN HARDLY describe the Middle East’s desert as barren land for it hides beneath its layers a bumper harvest of oil and gas reserves. Decades ago, following the discovery of oil, foresighted leaders in the region took the initiative to make the most of this natural asset and extend the value chain of oil and gas through increasingly complex processing activities within the region. Beginning with refining and basic petrochemicals the region’s downstream industry has, more recently, mastered the art of developing higher margin derivatives. Today, the Middle East is home to some of the top oil refineries and petrochemicals complexes in the world that boast state-ofthe-art large scale facilities, often integrated with advantaged economics. A large number of these facilities are based in the Gulf Cooperation Council state of Saudi Arabia, which is also home to the Sadara Project, the largest petrochemical facility built in a single phase. Qatar leads the GCC states in oil and gas reserves with an estimated proven bank of 13.1 per cent of the world’s natural gas, while Saudi Arabia commands 4.2 per cent and the UAE 3.2 per cent, which places the three nations among the top ten in the global rankings for gas reserves. This has strengthened the Middle East’s position as the leading oil and gas producer and established it as the primary global distributor of petrochemical products and a major player in refined products. The expansion has been driven by the growing demand in Asia and the Middle East’s low economics that helps displace products from European producers. For instance, China’s growth has been exceptional with demand comfortably outstripping domestic supply, and European refiners have been unable to compete with the economics of the Middle East. However, with the recent slowdown in Chinese growth we see the first signs of potential difficulties to come. Additionally, India and China have been building largescale downstream facilities with many due to come on-stream in the coming years. This becomes a greater cause of concern as India’s target markets are the same as that of the Middle East supplier. China is, 24
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The region hosts some of the world’s top refineries.
however, focusing on its domestic market – for the time being. The European refining industry is lobbying governments to ensure security of supply. The exact measures are as yet unknown but the political imperative for the region not to be totally dependent on external sources for such a vital resource is likely to be persuasive. Europe too has its own supplies of crude and a large refining and petrochemicals base. While the closure of the smaller weaker refineries is painful, this will leave the industry stronger with a few large, technically advanced refining hubs that can compete with external refiners. And finally, unconventional oil and gas from shale in the US has brought a new player into the market. These dynamics could easily upset regional supply-demand balances and undermine the Middle East’s position. Consequently, the Middle East cannot rest on its laurels and must continuously evolve its industry to stay ahead of the game through focusing on marginal improvement. The downstream industry in the region cannot become complacent.
But what can the industry do to protect this valuable income stream? Firstly, it must recognise that competition will get tougher and that proactivity is the need of the hour. Most Middle East refineries have deployed world scale and modern processing technology. Therefore, implementing huge projects such as new refineries or the latest technology that require huge capital expenditure (CAPEX) will not address the problem. Instead, refineries must focus on operational excellence, seeking the right balance of people, process and technologies to extract every cent of margin from these advantaged assets. Much of the knowledge crucial for achieving this objective is at hand for the Middle East’s regional refiners through their international partners. At the heart of this is technology and, as these international partners have already shown, this technology provides attractive returns, particularly when deployed on world scale assets. Operational excellence technologies can be grouped into four areas: control, people, asset, as well as safety and environmental.
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ďƒ¨ Analysis
Not surprisingly, the bedrock of Control excellence is the process control system. This needs to be capable of providing secure, reliable and stable control with open communications to gather all the essential real-time information that modern business processes need. Most control systems are reliable and stable, but many are not secure or open. Cyber security, an increasingly essential barrier to ensuring resistance to cyber-attacks and the consequent potential for serious interruptions to production, needs to be addressed as a matter of urgency. Open communications are essential if the control system is to effectively collect data from various sub-systems and then provide it to advanced technologies, people and business systems. Of the advanced technologies, model based supply chain planning and optimisation technologies can ensure that the right products are made at the lowest overall cost. Even the most sophisticated and automated plants are still reliant on their People for making informed decisions at the right time. Key to People excellence are tools that support empowerment, business process and training. In addition to
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Chris Hotblack sophisticated operator training simulators (OTS), best-in-class organisations rely on augmented reality and information delivery that provides people at different levels in the organisation with the right information, at the right time, in the right format and context.
Modern maintenance strategies focus on enabling the correct amount of maintenance to be done while minimising production impact. Asset excellence technologies includes those that support preventive and predictive maintenance, and enable organisations to take-action before damage is done or in the case of process equipment - such as heat exchangers when the economic benefit of intervention outweighs the cost of that intervention. Lastly, but definitely not the least, Safety and Environmental excellence, in many ways, is closely related to asset excellence, having at its core operational integrity. And key to this is putting in place the systems and processes so that staff from technicians to the boardroom can have confidence that the risk of incidents in the future have been well and truly minimised. The cost of achieving this is more than balanced by the on-going, dayto-day benefits, which such improved operational integrity brings. In conclusion, the Middle East’s downstream industry must not become complacent. Producers must continue to focus on operational excellence to help them keep their competitive advantage. â–
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E&P Gulfsands continues to look for opportunities to expand its business in Morocco.
Gulfsands making progress
in Morocco A IM-LISTED GULFSANDS PETROLEUM has provided an update on its activities underway in Morocco.
Rharb Drilling programme
Drilling operations on the Al Krima 1 well (AKR-1) located within the Rharb Centre Permit in Northern Morocco have now commenced using the recently imported COFOR SAS rig referred to in Gulfsands’ announcement of 10th July, 2013. The AKR-1 well is the first of nine wells to be drilled on the Rharb permits in two back to back drilling programmes. The AKR-1 well is planned to be drilled to a total vertical depth of approx. 1450 metres and is designed to evaluate two distinct Miocene aged reservoirs, contained within a fault bound structural closure, that have been identified from seismic data as having the potential to be gas bearing. The AKR-1 well is located very close to existing infrastructure, with the surface
Gulfsands Petroleum's Morocco assets
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location of the well lying within one kilometer of a gas export pipeline into which it is anticipated a successful well would be quickly tied in for delivery of gas to preexisting demand from local buyers. The company expects that drilling operations will be completed within 28 days.
Rharb Permit
The 3D seismic survey of approx. 220 sq-kms being carried out over the highly prospective south-western part of the Rharb permit area is nearing completion with final data capture expected to be completed by the end of
The company anticipates drilling at least one and possibly a second well on the Fes permit area
October. Thereafter the data will be processed for use early next year to assist the company in the further delineation of drilling targets for the remainder of Gulfsands’ nine-well drilling programme.
Fes Permit
The second seismic programme, designed to capture approx. 650-kms of 2D data on the prospective Fes permit, is continuing and is anticipated to be completed, subject to weather, early in 2014 with processing and interpretation to follow immediately thereafter. This 2D seismic program is designed to assist in the identification and prioritisation of additional drilling targets on the Fes permit and to more accurately define existing drill targets identified using the results of an earlier gravity survey programme and legacy 2D seismic data. The company anticipates drilling at least one and possibly a second well on the Fes permit area during 2014 using the data captured in this 2D seismic survey. The first well in this proposed three well programme is currently anticipated to commence drilling in the middle of next year. Mahdi Sajjad, the company's CEO commented: 'We are very pleased that Gulfsands has now begun drilling operations in Morocco and we look forward to seeing the results of this first well later next month. This significant milestone has been achieved as a result of the excellent co-operation we have received from the management of ONHYM, our government-owned partner in our activities in Morocco, and the commitment and important contribution of a number of our key technical and administrative personnel who we have drawn from our other projects in the MENA region to help get our activities underway as quickly as possible and to ensure we establish a cost effective operation in Morocco. “We continue to look for opportunities to expand our business in Morocco but for the moment, our number one priority and focus is on making a success of our Rharb drilling programme and to the early commercialisation of the gas resources we are targeting.” ■
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E&P
Marathon Oil receives go-ahead for Atrush development ENERGY COMPANY MARATHON Oil Corporation and its partners have announced that the Kurdistan Regional Government has granted them the right to commence the first phase of drilling on the Atrush block in the Kurdistan Region of Iraq. Operations on the Atrush-1 discovery well, located approximately 80 km northwest of Erbil, took place back in 2011. Plans for the new development involve drilling three production wells and a central processing facility will also be built, the company said. Marathon Oil and its associates expect to achieve first production by early 2015 with an average initial gross production of 30,000 barrels of oil per day (bpd). The Field Development Plan for Phase 1 has been granted a 25-year production period. The Atrush partners are currently undertaking appraisal activities and plan to drill a fourth well on the block.
DNO sets new production record in Iraq’s Tawke region NORWEGIAN OIL AND gas company DNO International has announced it has set a record rate of production 32,500bpd. The Tawke-23 well in Iraq has set the company back US$12mn to drill, complete and test, it revealed. The first horizontal well which was completed last year in the Tawke-20 field, set the previous record production rate for a Tawke well at 25,000bpd.
Valeura reveals Q3 operational results CANADA-BASED OIL EXPLORATION company, Valeura Energy, has announced its results for the third quarter of 2013, reporting an average of 1,000 boed, with production being up by 16 per cent in the second quarter of 2013. The third quarter of 2013 showed results for Turkish net production averaging around 960 boed, including 5.7mn cubic ft per day of natural gas at an average wellhead price of US$10.20 per thousand cubic feet and 12bpd. Canadian output, however, was reported to be around 40 boe/d. Valeura accquired land from Thrace Basin Natural Gas Corporation and Pinnacle Turket Inc., drilled and completed the second horizontal well BTD-4H in the Tekirdaf area. The well was drilled to a depth of around 100 metres into the Teslimkoy Formation, the company reported.
Iran drills 92 wells THE NATIONAL IRANIAN Drilling Company has announced around 92 oil and gas wells with a depth of 206,907 metres have been successfully spudded since the start of the current Iranian year. Hamid Reza Golpayegani stated that 43 were development wells, two were exploration wells and 50 were workover and complementary wells. According to Golpayegani operations on all the wells have now been completed by Iranian Central Oil Fields Company, six wells by Falat Quarreh Oil Company, 22 wells as commissioned projects and two exploration wells. “Of the conducted drillings, close to 30,851 metres pertained to energy project development projects,” Golpayegani said. Golpayegani stated 4,000 techno-engineering 30
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services were carried out on oil and gas wells; this involved 236 well-logging operations, 672 special operations, 229 mobile pipelines, 133 acidizing operations and 1,159 cementing assignments. “All the operations have been conducted by using 74 drilling units,” he added. Homayoun Kazemeini, the manager of development project of North Yaran Oilfield, disclosed that drilling operations of 18 wells have started since September 23. Once drilling operations of each well has been completed, production is expected to commence straightaway.
The US£$12mn Tawke-23 well has measured an oil production output of 32,500bpd. “The exceptional results from Tawke20 and Tawke-23 have fundamentally changed our approach to developing this field and also our expectations for its performance,” said Bijan MossavarRahmani, DNO International's executive chairman. “By any measure, these are prolific wells tapping into what increasingly feels like a sea of oil,” he added. Drilling operations have already taken place at two additional horizontal wells, Tawke-21 and Tawke-22, which are expected to be completed by the end of 2013. DNO International has a 55 per cent interest in the Tawke license, while Genel Energy plc has a 25 per cent stake and the Kurdistan Regional Government has control on the rest. DNO International has carried out projects in the Middle East and North Africa, with control over 20 blocks in various stages of exploration, development and production. The company operates both onshore and offshore in the Kurdistan Region of Iraq, the Republic of Yemen, the Sultanate of Oman, the UAE, the Tunisian Republic and Somaliland.
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OMV announces new oil find in Libya AUSTRIAN ENERGY COMPANY OMV AG, oil and gas company Repsol SA of Spain and Total SA of France have recently made an oil discovery in Libya. The oil discovery named A1-129/02, was drilled to a total depth of 1,836 metres, the first in Libya by OMV and its partners since the revolution back in 2011. Repsol has a 40 per cent interest in the project, while OMV and Total both have a 30 per cent interest. Drilling in the area commenced back in OMV said it plans to increase its total oil production May 2013 with the discovery being made in output to 350,000bpd the Murzuq Basin, 800 km south of the capital Tripoli, stated OMV, who has joined forces with French energy company Total. Drilling is expected to continue until the end of 2015 . “The discovery in Libya confirms the potential of the country for OMV’s upstream activities,” said Jaap Huijskes, OMV executive board member for exploration and production. In 2012, OMV produced 29,500 bpd in Libya, however, the company said it now plans to increase its total output to 350,000 bpd by 2016. Repsol operates the block with a 40 per cent stake, alongside Austria’s OMV and Total of France, both holding a 30 per cent share. “Following the good results obtained, Repsol will continue with the exploratory campaign, which began in 2013 and which will continue through the end of 2015,” the company said in a statement. OMV was founded in Libya in 1975 and began production in 1985.
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Algeria announces major oil discovery ALGERIA'S SONATRACH HAS discovered an oilfield with estimated reserves of US$1.3bn barrels in the region of Tamguid Messaoud near Ouargla city. “This is one of Sonatrach's biggest discoveries in the past 20 years as it is an accumulation of some 1.3bn barrels," Algeria’s energy minister Youcef Yousfi stated. The finding was made by Sonatrach not far from Algeria's biggest oilfield, Hassi Messaoud. According to Sonatrach official, Said Sahnoun, Yousfi stated that the company would have to use non-conventional methods to retrieve oil from the new field including hydraulic fracturing, also known as fracking. The minister highlighted that the field will be exploited in the next three to four years. Yousfi revealed that Algeria expects to double its gas production in the next seven to 10 years after making a number of significant oil and gas finds in maturing and new fields.
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E&P
Oryx Petroleum makes crude oil discovery in Iraq ORYX PETROLEUM CORPORATION Limited has announced the discovery and testing of crude oil at Ain Al Safra in the Kurdistan Region of Iraq. The company will assess the Ain Al Safra discovery in 2014 as part of the multi-well appraisal and development drilling programme in the Hawler license area. Oryx Petroleum operates the oilfield which has a 65 per cent participating and working interest, it said. “We are very pleased to make a second oil discovery on the Hawler license area,” said Henry Legarre, Oryx Petroleum's chief operating officer. “Based on the results of the recently completed test programme at Ain Al Safra, we are proceeding with further analysis and appraisal to determine the size and quality of the discovery as well as its potential commerciality. “We look forward to working with our partners to appraise this new discovery,” Legarre added. Oryx Petroleum The Sakson Hilong 10 rig drilled the exploration well targeting the Ain Al Safra prospect in the Hawler license area in early June. The AAS-1 well targeted oil potential in the lower Jurassic and Triassic and in the Cretaceous. Netherland Sewell & Associates, Inc. calculated in March that the Ain Al Safra prospect held around 225 MMbbl of unrisked gross (100 per cent) prospective resources.
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PDO completes drilling at Nimr oilfield HYDROCARBON EXPLORATION AND production company, Petroleum Development (PDO) has made history after announcing it has drilled the 1000th well at its Nimr oil field. The NM-1000 well has been drilled around 3km south west of the field’s first well, NM-1. According to PDO, the well is still in operation following its discovery 33 years ago. The wells, based at Nimr, which is in the southern part of PDO’s concession area, has reportedly produced 625mn barrels of oil with another 132mn barrels of reserves in the pipeline. PDO stated that the new well which is now in production, was spudded by PDO rig-82 and took 23 days in total to complete to a depth of 2,100 metres. “This is a real landmark both for the company and the country and I am immensely proud of the diligence, dedication and expertise of all those associated with the field,” stated PDO managing director Raoul Restucci.
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Marathon struggles to exit Libya LIBYA HAS BLOCKED efforts by U.S. company Marathon Oil to sell its stake in one of the country's top oil ventures by moving to pre-empt a deal, sources said, highlighting the struggle investors face in cutting exposure to Libya's unrest. Two years of turmoil since the Arab Spring and tough contract terms have prompted oil firms to reassess their role in Libya, and U.S. companies appear keenest to leave as they lack the proximity and infrastructure links that make North Africa attractive to their European peers. A senior Libyan oil source told Reuters that Marathon had decided against selling the stake after talks with NOC. Contracts require foreign oil companies to secure NOC approval for any sale and also give it the right of first refusal in the event of any sale, the source said. 'The company has changed its mind,' he told Reuters. 'Marathon as a partner indicated its desire to sell its shares. It had talks with the NOC and before receiving approval, I believe things changed for the company.’
PDO completes 1,000 wells PETROLEUM DEVELOPMENT OMAN (PDO) has announced that it has completed drilling the 1,000th well on its Nimr oilfield, located south of Muscat The well - NM-1000 - has been developed around three kilometres south west of the field’s first well, NM-1, which is still in production after its discovery 33 years ago, a company statement said. According to PDO, the 1,000 wells at Nimr, which is in the southern part of PDO’s concession area, have reportedly produced 625mn barrels of oil with another 132mn barrels of reserves in the pipeline - an average ultimate recovery of 700,000 barrels per well. Junaid Mohiddin Ghulam, Nimr Cluster leader at PDO, said, “Besides being the first oil field in Oman to achieve this milestone, NM-1000 symbolises the persistence, resolve and sustainability of the team to produce oil from some of the most challenging subsurface environments.” The well was drilled by PDO Rig-82 over a 23day period in the Middle Gharif sandstone reservoir to a total depth of 2,100 metres and is now in production, the company added. Nimr, PDO’s largest field in terms of crude oil production, has a further 150mn barrels currently being matured through field trials and studies and polymer injection trials have just commenced, the company added. 36
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E&P ďƒ§
Petrofac awarded Iraq project OILFIELD SERVICE PROVIDER Petrofac has received a contract extension from the South Oil Company (SOC) for the Iraq Crude Oil Expansion Project located in Al Fao Peninsula The original contract was awarded in August 2012 for 12 months following a three-month mobilisation period and was worth approximately US$100mn. The 12-month extension, effective from November 2013 and worth US$99mn, includes the second phase of the project and will likely see the company provide an additional scope of operations and maintenance services. Petrofac added that the extension was a follow-up of the original contract awarded in 2012 for Phase One of the project, which covered operations and maintenance services on the offshore facilities, including an offshore platform and metering station.
www.petrofac.com
Repsol makes Libyan discovery REPSOL AND ITS partners OMV and Total have announced that it has discovered oil in the Murzuq Basin onshore Libya The discovery was made in Block NC115 in the Sahara desert, 800-km south of Tripoli, a company statement read. The Spanish oil explorer said that the well, A1-129/02, was drilled to a total depth of 1,836 metres and produced good oil flows during initial testing. The well flowed 528 bpd with a choke size of 32/64 inches and a perforated interval of 1,372-1,378 metres in the Mamuniyat formation. It is the third of eight wells that have been planned to be drilled in the block, which covers 4,400 sqkm and has shown www.repsol.com ‘excellent reservoir properties’, Repsol added. Repsol has a 40 per cent stake in the block, while OMV and Total have a 30 per cent stake each. Meanwhile, Libya is close to producing 40,000 bpd from its Bouri oilfield, offshore Mediterranean Sea The Oil Ministry has confirmed that it plans to add up to 15,000 bpd within six months through the launch of new drilling technology, sources said. The oilfield is located about 130km north of Tripoli and is reportedly the country’s biggest offshore field. The Bouri oilfield, where production started in 1988, is run by the Mellitah Oil and Gas Company, a joint-venture between Italy’s Eni and the state-owned National Oil Corporation.
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Gas ďƒ§
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HE US SHALE oil and gas boom continues apace with the country now standing shoulder to shoulder with, and many say ahead of, Saudi Arabia and Russia regarding production levels. “With output of more than 10mn barrels per day for the last two quarters, its highest in decades, the nation is set to become the largest non-OPEC liquids producer by the second quarter of 2014, overtaking Russia,� wrote the International Energy Agency (IEA) recently. “And that’s not even counting biofuels and refinery gains. The United States’ place in the driver’s seat of growth is [...] a throwback to decades past.�
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Gas
The IEA statement that US liquids production will average 11mn bpd in 2014 versus 10.86mn in Russia will have surprised few. Neither will the prospect of the US becoming the world’s largest oil and gas producer, with some industry analysts saying that the US is already in some respects ahead of Russia and Saudi Arabia. A recent release from US energy consultancy, PIRA Energy Group, backed this view, stating that total liquids produced by the US, including supplies such as crude oil, condensate, natural gas liquids and biofuels, will average around 12.1mn bpd in 2013 and see the US overtake Saudi Arabia as the world’s top supplier. The growth in US output, which has grown by 3.2mn bpd since 2009, is the fastest expansion in production over a fouryear period since Saudi Arabia’s output surged between 1970 and 1974, according to PIRA. The increase in oil and gas from shale, from areas such as Eagle Ford in Texas and the Bakken in North Dakota, has seen US supply grow by one million bpd in 2012 and again in 2013. This is the result of the well-publicised concerted efforts by the US Department of Energy to increase exploration and hone hydraulic fracturing, or fracking, and horizontal drilling techniques in recent years to exploit such previously hard-to-access unconventional oil and gas reserves. “[The US] growth rate is greater than the sum of the growth of the next nine fastest growing countries combined and has covered most of the world’s net
demand growth over the past two years,” wrote PIRA. Output from Saudi Arabia has still risen but has been outstripped by the US, according to the US consultancy. PIRA added, however, that the US does currently lag behind both Saudi Arabia and Russia in the production of just crude oil by about three million bpd. “It is a significant reminder to look beyond Saudi Arabia,” said vice president of upstream research at IHS CERA, Peter Jackson, in a recent statement. “The US will become the largest oil and gas producer, and the trend will only continue. Russian production is stable but production in the US is rising. Before the tight oil revolution people thought oil supply would start to fall slowly in the longer term, but now it is booming.” Any fears of a US-triggered global gas price crash would seem to be unfounded however. While the number of unconventional natural gas wells is expected to continue increasing until at least 2020, the huge economic benefits many predict may be tempered by the fact that shale gas recovery is a timeconsuming, logistically challenging and costly process. As Peter Voser, chief executive of Royal Dutch Shell, told the UK’s Telegraph newspaper recently, “Cheap US gas going into the rest of the world and therefore changing the pricing structures across the world [is a] myth.” Voser added that the cost of liquefying,
The US Department of Energy has invested heavily in improving hydraulic fracturing and horizontal drilling techniques in recent years
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transporting and re-gasifying the gas would mean that the cost of any US exports of shale gas would be on a level with existing market prices. And even if global gas prices were threatening to dip due to an influx of cheap US exports, BP’s chief economist, Christof Ruehl, was quoted as saying recently that Saudi Arabia and the other OPEC members would act quickly to “neutralise” the effect of the additional supply. A ban imposed in the 1970s is still in place on almost all US oil exports, meaning that the country’s increased production is merely making it more self-sufficient. Indeed, shale oil has seen the US drop behind China as the world’s biggest oil importer, according to the US Energy Information Administration (EIA). There have been calls for greater US LNG exports, however, and it is a step that is reportedly being seriously considered. Delegates from 10 countries, including the Czech Republic, Hungary, Haiti, India, Japan, and Thailand, recently argued for such a move at a House Energy and Commerce Subcommittee on Energy and Power forum, saying that it would increase global energy security. New technology may play a significant role in dictating future gas prices. As Peter Jackson pointed out, a combination of technological advances and higher prices were responsible for making the recovery of shale gas affordable in the first place. “The markets are focused on the short term, but will see stability long term as these new technologies help drive supply,” said Jackson. “Five or ten years ago everyone worried about peak oil and had a fear that oil supply would quickly decline and drive up prices. “But the US tight oil and shale gas revolution shows us that when the price rises then new technologies become viable and technology steps in to help boost oil and gas supply from previously uneconomic sources. These new technologies are the key to growing supply long term.” Jackson said that the ongoing surge in US production would “reshape markets”. “It will change the trade flows considerably,” he said. “This has an impact on the direction of exports around the world changing direction, from West to East, to China for example. And also sweet African crudes are now switching globally, less directed to the US and increasingly now to Asia. “Other countries are impacted. Some of the counties that traditionally supplied the US are having to find other customers for their oil in alternative markets. So this means you can see the OPEC countries shifting their focus to Asia instead of supply the US.”
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Gas
But while the US is self-reliant when it comes to high-quality light, sweet oil, US imports of heavy and sour crudes from countries such as Saudi Arabia have actually increased in the past three years. Saudi Aramco has also invested in US refineries to further strengthen energy ties between the two countries. Jackson added that while there may be some short term “softness” in prices, largely due to the ongoing flatness of the global economy, a long-term strong supply of oil and gas would simply serve to continue to boost the economy in certain territories. “Alongside that you need to consider concerns about the situation in the Middle East, the situation in Syria and the longer term situation across the Middle East which will persist,” said Jackson in the IHS CERA statement. “We see short term softness in the prices and an increase in the medium term as economies grow and demand increases.” In the short term, high US production may help compensate for OPEC production disruptions in member countries such as Libya and Iraq and keep prices in check. OPEC crude supplies recently slipped to
below 30mn bpd for the first time in almost two years according to the IEA, despite Saudi Arabia’s output breaching the 10mn bpd mark for the third consecutive month. The fall is also due in part to the ongoing sanctions on Iran’s oil sector. Despite the recent thawing of tensions between Washington and Tehran, observers expect sanctions to remain in place. “Most expect that turning the clock back on sanctions will be a drawn-out process based on tangible diplomatic progress with regard to the issues at hand, which many still view as a remote prospect,” said the IEA. With Saudi Arabia making concerted efforts to diversify its economy away from oil and gas reliance and to improve its energy mix by embracing renewables, its domestic consumption may be reduced, meaning it can conserve more oil and gas for export and prolong its position as one of the top producers, if not the top producer, globally. But with current trends apparently set to continue over the longer term, PIRA seems correct in its assertion that “the US position as the largest oil supplier in the world looks to be secure for many years”. ■
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Gas
Qatargas, E.ON arm sign five-year LNG deal QATARGAS 4 AND E.ON Global Commodities, the energy trading business of E.ON, have signed an LNG sale and purchase agreement (SPA) for five years, starting from 2014 and covering a volume of approximately 1.5mn tonnes of LNG a year. The LNG will come from Qatargas 4 (Train 7), a joint venture between Qatar Petroleum and Shell, and will be delivered on-board QMax LNG vessels to the Gate LNG Terminal in Rotterdam, Netherlands. Qatargas CEO Sheikh Khalid bin Khalifa al-Thani said, “The signing of this agreement represents a significant step for Qatargas in the development of its global strategy. We are delighted to have E.ON Global Commodities as a partner.” Qatar minister of energy and industry and Qatargas chairman Dr Mohamed bin Saleh al-Sada signed the SPA at the Four Seasons hotel in Doha on behalf of Qatargas 4, while E.ON Global Commodities CEO Christopher Delbrück and director of LNG Richard Baylis signed on behalf of E.ON. Delbrück said, “This contract represents a significant step in the development of our global growth strategy and is a major
Christopher Delbrück signed the SPA with Dr Mohamed bin Saleh al-Sada. achievement in forging a long-term partnership with Qatar.” Baylis added, “I am very pleased that we have been able to conclude this agreement with Qatargas. It is the culmination of a lot of effort from both companies over a number of years to find a suitable agreement in a rapidly changing LNG marketplace.” Qatargas delivered its first LNG cargo to the Gate receiving terminal in Rotterdam in July 2013 under a master sales and purchase agreement (MSPA) signed between the two companies in 2011.
Algeria gas production ‘to double in 10 years’ ALGERIA’S NATURAL GAS and oil output should double in seven to 10 years as it brings on stream fields in under-explored regions, the country’s energy minister, Youcef Yousfi, said. The North African nation is currently finding oil and gas in the eastern region, where most of its producing fields are located, Yousfi said. Algeria plans to step up exploration in the south-western region, start offshore drilling and develop shale and tight gas reserves, he added. “In the mature basins in the southeast of the country, under the existing fields of natural gas, condensates and oil, we have made significant discoveries,” Yousfi said. According to Bloomberg, Algeria’s oil production tumbled in July 2013 to 1.12mn barrels per day – the lowest level since 2003 – as security concerns, corruption probes and delays in granting exploration licenses restrained its ability to bring new oil on stream. Yousfi said the country’s daily oil output was 1.2mn barrels. New finds have added at least one billion barrels to the reserves of Hassi Messaoud,
The Kechba gas plant
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Algeria’s oldest field, that supplies about a third of its oil production, he said. The ministry is in the process of evaluating little-explored regions in the southwest of the country, where some oil and gas finds were recently made, he added. An auction of onshore exploration rights, initially planned for February 2013, should be held in two or three months to sustain the exploration effort, and an offshore well will be drilled for the first time in 2014, Yousfi said. “We have between 300 and 500 technically recoverable trillion cubic feet (tcf) of gas in tight gas. We are progressing in the evaluation of shale gas in the country and it’s above 700 tcf,” he commented. Algeria is keeping export volumes unchanged by finding new customers to offset a drop in European fuel consumption that hurt sales to the continent, Yousfi said. “We have accepted to reduce our exports to these countries for a small period of time but generally we didn’t reduce our production. We are exporting some quantities to new markets,” he concluded.
BP discovers gas in East Nile Delta, Egypt BP EGYPT HAS announced a significant gas discovery in the East Nile Delta. The deepwater exploration well, named Salamat, is the deepest well ever drilled in the Nile Delta, BP said. It is the first well in the North Damietta Offshore Concession granted in February 2010 and operated by BP. According to BP, the well was drilled using the sixth-generation semi-submersible Maersk Discoverer rig at a water depth of 649 metres and reaching a total depth of approximately 7,000 metres. Mike Daly, executive vice president of exploration at BP, said, “Success with Salamat proves hydrocarbons in the centre of a 50-km long structure. With a hydrocarbon column in excess of 180 metres, the discovery increases our confidence in the materiality of the deep Oligocene play in the East Nile Delta.” The wireline logs, fluid samples and pressure data confirmed the presence of gas and condensate in 38-metre net of Oligocene sands in Salamat. Further appraisal will be required to better define the field resources and to evaluate the options for developing the discovery, BP said. Hesham Mekawi, BP Egypt regional president, said, “The Salamat discovery is a great outcome for our first well in this core exploration programme in the East Nile Delta. It shows our commitment to meeting Egypt’s energy needs by exploring the deep potential offshore the Nile Delta. Standalone and tie-back to the nearby Temsah infrastructure development options are currently being evaluated." The Salamat discovery is located around 75km north of Damietta city and 35km to the north west of Temsah offshore facilities.
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Gas
Oman Gas Company imports gas pipelines via Port of Duqm THE OMAN GAS Company (OGC) said it recently took delivery of its largest shipment of pipelines via the strategically located Port of Duqm. The shipment, comprising 85km of 32inch pipelines, will be utilised in OGC’s pipeline expansion projects. OGC said it is undertaking significant expansion of its gas transportation infrastructure to help in the development of the country’s gas sector. This expansion is being carried out through a series of projects presently under way in different areas of the country. According to the company, the expansion projects are in line with its
mission and vision to be a world-class midstream gas value chain company in Oman and also to contribute to the country’s value by developing and operating oil and gas facilities to international standards through innovation, efficiency and development of local talent. OGC delivers natural gas to economic sectors and major consumers comprising of domestic, power and desalination plants, fertiliser, methanol, petrochemical, refinery, steel and cement plants. To support the development of the country, the Port of Duqm is positioning itself as the preferred gateway for project
cargo and general cargo related to this industry. The port is currently finalising the purchase of specific equipment to handle oil and gas related cargo. The Port of Duqm officially started its ‘soft operation’ in March 2013 and currently employs approximately 90 people, the large majority of which are Omani nationals. The Port of Duqm Company (PDC) is a joint venture company between the Oman government and the Consortium Antwerp Port (CAP). PDC manages and operates the port of Duqm and is also responsible for developing and managing the port industrial area at Duqm.
Saudi Arabia to use shale gas for electricity generation SAUDI ARAMCO HAS announced that Saudi Arabia is preparing to be among the first countries outside North America to use shale gas for power generation and thereby save more of its crude oil for exports. At the recent World Energy Congress in Daegu, South Korea, Saudi Aramco CEO Khalid Al-Falih said, “We are ready to start producing our own shale gas and unconventional resources in various types in the next few years and deliver them to consumers. “Only two years after launching our own unconventional gas programme, in the northern region of Saudi Arabia, we are ready to commit gas for the development of a 1,000MW power plant which will feed a massive phosphate mining and manufacturing sector,” added Al-Falih. The Saudi Arabian Mining Co. (Maaden) also plans to invest in a phosphate project which is part of a new industrial city called Waad Al-Shimal City for Mining Industries, with production expected to start by the end of 2016. By unlocking its gas reserves, Saudi Arabia could use the fuel to power its domestic economy and allow more room for oil sales to world markets, Saudi Aramco said. Petroleum and Mineral Resources minister Ali Al-Naimi estimated that Saudi Arabia offers more than 600 tcf of unconventional gas reserves, more than double its proven conventional reserves. According to industry sources, however, Riyadh – which is hampered by scarce water and prices fixed far below production costs – is unlikely to produce much shale gas this decade. Saudi Aramco meanwhile has been mapping unconventional
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Saudi Arabia is preparing to be among the first countries outside North America to use shale gas for power generation.
reserves in the hope it will help meet an expected doubling of demand by 2030 in a country that bans gas imports. The company has carried out appraisal drilling and piloting of three prospective areas for unconventional gas in the northwest, in south Ghawar and for condensate-rich shale gas in the Rubí Al-Khali. The gas will feed a proposed power plant in Jizan, which will be connected to a 400,000 bpd refinery, Saudi Aramco said. The Saudi state oil giant hopes to complete the project by early 2017, Al-Falih said.
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Petrochemicals
GCC fertiliser production capacity
‘to rise by 47 per cent’ The Gulf Petrochemicals and Chemicals Association estimated this after considering projects currently in the pipeline.
T
HE GULF PETROCHEMICALS and Chemicals Association (GPCA) has estimated that the GCC fertiliser industry’s production capacity will increase by 47 per cent from 2012 levels to 46.6mn tonnes by 2018. The GPCA arrived at this estimate after considering the fertiliser projects currently planned, pegged at US$10bn. In 2012, the fertiliser production capacity of the six GCC nations (UAE, Saudi Arabia, Qatar, Kuwait, Oman and Bahrain) was around 31.4mn tonnes. The industry’s capacity has been estimated to grow by ten per cent per annum over the next five years. According to the GPCA report, global fertiliser demand would increase 1.8 per cent each year.
The GCC’s fertiliser industry must continue to improve its cost-leadership in order to retain its global competitiveness LNG imports in countries like the UAE and Oman have increased as it is used in electricity generation. Gas production has also gone up in Qatar and Saudi Arabia, so the increasing LNG imports and production is expected to pave way for the development of downstream industries like fertilisers. According to the report, the GCC fertiliser industry is also poised to gain from the region’s push towards renewable energy, as this could help address feedstock challenges in fertiliser production, particularly for natural gas.
The industry is poised to gain from the region’s push towards renewable energy CRU consultant Kevin Breen said, “Currently, power generation takes up a lot of natural gas, but if renewable technology like photovoltaics are introduced in the GCC, it would help the petrochemicals and fertiliser industries.” GPCA Secretary General Dr Abdulwahab al Sadoun said that fertiliser companies should look at environmental conservation practises even as they strive to maximise profits. At the recent Fourth Annual GPCA Fertiliser Convention, Al Sadoun pointed out, “The GCC’s fertiliser industry is a cost leader and must continue to improve its cost-leadership in order to retain its global competitiveness. Many producers in the region have implemented strategies to reduce greenhouse gas emissions, recover carbon dioxide and reduce water consumption.” ■
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Petrochemicals
SABIC CEO calls for change in Europe AT THE RECENTLY held European Petrochemical Association (EPCA) annual meeting in Berlin, Mohamed Al-Mady, Saudi Basic Industries Corporation (SABIC) CEO, said, “Europe faces a new reality. The European chemical industry and various governments need to focus on more resource and cost-efficient manufacturing, targeting incentives for innovation at the development stage and instituting a robust regulatory framework based on good science with clear goals. Governments must proactively support this transition — it cannot be done by industry alone.” With regards SABIC’s operations in Europe, he said the company will continue to play an active role in the region, striving to maintain its in-market manufacturing presence, providing technology from a growing innovative portfolio, and utilising the optimal value chain to develop solutions to both Europe’s shifting demographic profile and exportable goods and technologies. He said that SABIC’s manufacturing capabilities in the continent will target and invest in more resource and cost efficiency, which will in turn improve the company’s environmental footprint. Al-Mady added that SABIC would develop technology from its multiple research facilities around the world. “Technology and innovation are central to our future success in Europe as well as the rest of the globe,” he said. For SABIC and other global companies to effectively contribute toward Europe’s economic growth, Al-Mady asked the governments for proactive and coordinated support in the region. For one, he called for “a robust regulatory scheme for more resource and cost efficient manufacturing.”
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Mohamed Al-Mady, SABIC CEO He said that historically European industry’s strength has been its ability to confront difficult challenges and create viable alternatives to achieve greater success.
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Petrochemicals
APICORP buys stake in Egypt’s EMethanex
SIPCHEM commences operations at Jubail plant SAUDI INTERNATIONAL PETROCHEMICAL Company (SIPCHEM) has announced that it has commenced operations of utility and offsite units, and initial operation of some process units of ethylene vinyl acetates (EVA) and low density poly ethylene (LDPE) plant at its complex in Jubail Industrial City. The phase includes installation and testing of major equipment and pre-manufactured modules, whose installation and testing required longer time, prior to completion of basic preparations for initial startup expected during Q4 2013. The plant capacity is 200 KTPA of ethylene vinyl acetates (EVA) and low density poly ethylene (LDPE). EVA and LDPE products are in line with the company’s strategies to implement downstream projects that are integrated with SIPCHEM’s current products to satisfy local needs and in addition to meet international demand. The total cost of construction of this project is US$800mn. SIPCHEM owns 75 per cent of International Polymers Company (IPC) while Hanwha Chemical Company of Korea owns 25 per cent. Meanwhile, Saudi Arabia has also said that it has plans to build new petrochemical projects with their values at US$70bn. Saudi Arabian Oil Company (Saudi Aramco), Saudi Basic Industries Corporation (SABIC) and Farabi Petrochemical
The Jubail plant capacity is 200 KTPA of ethylene vinyl acetates (EVA) and low density poly ethylene (LDPE)
Company (Farabi) will lead investments in these projects, Arab News quoted prtrochemical sources. The projects are likely to be constructed near the oil refineries to get their required feedstock. They would be located in Jazan, Yanbu and Ras Tanura, it added. The Kingdom also recently started industrial and petrochemical projects in Jubail and Yanbu industrial cities with costs reaching US$87bn. The projects would raise the country’s share to global petrochemical market to more than 12 per cent and its petrochemical products to nearly 100mn tonnes annually. Saudi Arabia's petrochemicals sector will continue to play a central role in the development of the country'snon-oil industrial sector, helping to balance an ongoing decline in oil production.
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ARAB PETROLEUM INVESTMENTS Corporation (APICORP) has RECENTLY bought additional ten per cent stake in Egyptian Methanex Methanol Company (EMethanex) from Canada-based Methanex. The US$110mn transaction would increase APICORP’s share in the joint venture to 17 per cent, the company said in a press release. Following the equity transaction, Methanex will continue to remain the operator and majority shareholder of EMethanex with just over 50 per cent ownership. The remaining 33 per cent interest is held by the Egyptian government. The company’s production facility is in Damietta and the plant is considered one of the most energy efficient methanol plants in the world. With a production capacity of 1.3mn tonnes of methanol per year, it supplies both local and global methanol markets.
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Petrochemicals
US$26.6 billion boost for Saudi Arabia’s petrochemical industry SAUDI ARABIA PLANS to invest nearly US$26.6bn aimed to enhance petrochemical industry and raise the production capacity from the current level of 170mn cubic metres to 226mn cubic metres, or an increase of 33 per cent, by 2015. According to a report published in Zawya, the petrochemical sector has, however, witnessed an 8.2 per cent decline since the beginning of the current year in terms of revenues as investors’ fears over low global demand Saudi Arabia reportedly ranks first and second in the on petrochemical products. production of methanol and ethylene, respectively, the Saudi Arabia reportedly ranks first and two essential components in petrochemical industry second in the production of methanol and ethylene, respectively, the two essential components in petrochemical industry. The petrochemical industry in Saudi Arabia is said to have enjoyed the biggest growth in the Middle East due to its adoption of global competition strategy and resting on huge oil reserves of 264bn barrels and 279.2 trillion cubic metres of natural gas. Meanwhile, another report released by Alpen Capital said that a big growth in the production of ethylene and polyethylene is forecast in the Kingdom to reach 226mn cubic metres in 2015 compared to the current level of 170mn cubic metres.
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Al Sejeel project’s launch in 2018: IQ THE US$615MN AL Sejeel Petrochemical Complex is currently on track with commercial launch expected in 2018, Industries Qatar (IQ) announced. Al Sejeel is expected to boost ethylene at 707,921 cubic metres per year and add highdensity polyethylene at 470,059 cubic metres per year to the group’s product list, said IQ’s chief co-ordinator Abdulrahman Ahmad al-Shaibi. “Following the signing of a heads of agreement with Qatar Petroleum in the early part of 2012, and subsequent appointment of Qatar Petrochemical Company Limited (QAPCO) as project manager, the project is progressing satisfactorily through the frontend engineering design phase with the recent selection and appointment of polyethylene and polypropylene technology providers.” Al-Shaibi added that the petrochemical complex, which included a world-scale ethane/butane/naphtha mixed-feed steam cracker, remained an important part of IQ’s growth and diversification plans for the latter part of the decade.
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Iraq
The Iraqi authorities are now focusing on monetising natural gas reserves but it must first develop an efficient infrastructure. Moin Siddiqi reports.
Capitalising on
Iraq’s gas potential Three-quarters of proved resources are associated with crude oil (ie, associated gas), concentrated in the south, mostly super-giant oilfields such as Rumaila.
A
CCORDING TO IRAQ’S Ministry of Oil (MoO), capital expenditures of US$30bn per year in energy infrastructure are required to meet ambitious targets for oil and gas production by the end of this decade. Much also depends on cutting bureaucratic red tape and offering favourable contract terms to foreign energy groups in Iraq. The country’s provable natural gas reserves as of end-2012 were reported by BP to be 126.7 trillion cubic feet (tcf) – of which 60 per cent lie in the southern region. Three-quarters of proved resources – equivalent to 95 tcf – are associated with crude oil (ie, associated gas), concentrated in the south, mostly around the super-giant oilfields of Rumaila, West Qurna, Majnoon, Nahr Umr and Zubair. The bulk of non-associated gas, totalling some 32 tcf, is in northern Iraq, particularly in the Kurdistan Regional Government (KRG) area, as well as spread across a small number of fields, including Ajil, Bai Hassan, Jambur, Chemchemal, Kor Mor, Khashem alAhmar, and al-Mansuriyah. There is also a potential in the west, where resources are
thought to be large, but problems of attracting operators to exploration onshore blocks and long distance from major demand centres thus far deter production. At the time of upward revision to provable oil reserves in 2010, the figure for proven gas reserves was left unchanged, although new estimations were justified because of a higher share of associated gas. In fact, “ultimately recoverable resources” are estimated to be significantly larger, at 7.9 trillion cubic metres (tcm), or 280 tcf, of which around one-third is reckoned to constitute non-associated gas. This means that almost 2.6 tcm of the resources yet to be explored are expected to be in nonassociated fields.
The composition of associated gas varies considerably between north and south of the country
The composition of associated gas varies considerably between north and south of the country. Associated gas in the south has a relatively high content of natural gas liquids (NGLs), whereas the gas produced in the north is somewhat drier but also requires additional treatment in order to make the gas marketable.
Wasteful practice
Iraq lacks the utilisation infrastructure to produce ‘associated gas’ (gaseous byproducts of oil extraction), which explains its practice of gas flaring over several decades. According to the US National Oceanic and Atmospheric Administration (NOAA), Iraq was the fourth largest natural gas flaring country in 2010. Iraqi gross annual gas production rose from 81bn cubic feet (bcf) in 2003 to 660 bcf in 2011 – in tandem with rising crude output that increased from 1.34mn bpd to 2.81mn bpd during the same period. Some of this gas is used as feedstock for power generation, whilst a smaller portion is reinjected to enhance oil recovery. However, the bulk of Iraqi natural gas is simply flared.
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Iraq
Flaring losses in some months have exceeded 60 per cent of production, or more than one billion cubic feet per day, due to a lack of sufficient pipelines and other infrastructure to transport gas for consumption and export. Consequently, Iraq’s five processing plants, with combined annual processing capacity of 773 bcf, are currently mostly sitting idle. Investments into new or rehabilitated gas processing facilities have lagged recent expansion in oil output. Thus, as of 2012, Iraq had the annual capacity to process only eight billion cubic metres of raw gas. There is only a very limited national distribution network. The conflict-ridden country faces a major challenge to gather and process all the associated gas that will flow as oil production rises rapidly towards planned nine to 10mn bpd level by 2017-2020. The speed at which Iraq builds new gas gathering and processing capacities shall determine the pace at which it can realise its goal of reducing gas flaring. Raising oil production capacity over the longer term requires substantial increases in natural gas and/or water injection to maintain oil reservoir pressure – especially in matured oilfields.
According to the US National Oceanic and Atmospheric Administration (NOAA), Iraq was the fourth largest natural gas flaring country in 2010.
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Gas-fired power capacity
Exploration and appraisal of ‘untapped’ natural gas resources is at a nascent stage and limited production is mostly confined to the north, while non-existent in the west, although both areas boast strong prospects. Due to the petroleum sector’s long domination, gas has historically been a secondary consideration; but emphasis on ‘gas-prone’ areas is growing as domestic demand soars, especially for power generation across the country (the size of France).
The speed at which Iraq builds new gas gathering and processing capacities shall determine the pace at which it can realise its goal to reduce gas flaring
The Ministry of Electricity plans to triple generating capacity to 27 GW by 2015. More than 20 new contracts have been signed for the construction of power plants (the majority of the new power stations will be gas-fired). In addition, Iraq plans to spend an additional US$27bn over the next five years, with about half of funding towards upgrading the transmission and distribution systems. It also wants to convert ageing gas-fired plants to more efficient combined-cycle plants. An expansion of generating capacity will be linked to the development of the gas industry infrastructure. New pipelines are needed to carry natural gas, which would otherwise be flared, to future power stations. The hydrocarbons industry is the largest single industrial customer of electricity in Iraq. Future increases in oil production require substantial power generation capacity. But after the turmoil in 2003, Iraq has struggled to keep pace with electricity usage, resulting in severe bottlenecks. Although new generating capacity is planned in the coming years, delays in meeting projected targets would lead to significant shortfalls to meet higher
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S12 ORME 7 2013 Iraq 01_Layout 1 01/11/2013 15:09 Page 60
Iraq
trade volumes in 2030 at between 15 and 30 bcm. European markets are projected to require almost 200 bcm in additional gas imports as demand surges and indigenous output drops. Plans to export natural gas are controversial because gas is badly needed as a cheap feedstock for electric power plants. The current shortage of adequate gas feedstock has led to idle and sub-optimallyfired electricity generation capacity.
demands of the petroleum sector. In addition, Iraq will need to enact regulatory and tariff reforms to attract private domestic and foreign investments in Independent Power Projects (IPPs).
Export capacities
Given political normality, good contractual terms and a proper infrastructure, Iraq, too, boasts real export possibilities, including: • Developing the proposed northern Nabucco pipeline via Turkey to Europe, which could transport 530 bcf per year to Europe, according to estimates. • Connecting the national gas grid to the existing ‘Arab Gas Pipeline’ which ties up with Egypt’s gas grid, plus those of Jordan, Lebanon and Syria. Under this scheme, natural gas would be piped from Iraq’s Akkas field to the Turkish border and then onto mainland Europe. • Building liquefied natural gas (LNG) facilities in the Basrah region, which would provide Iraq with a lucrative outlet to Asian-Pacific markets.
Under the accord, processed gas would go to the state-owned South Gas Co. for domestic use, mainly to produce electricity. The implementation of the HoA is needed for several new oil development projects (which depend on natural gas for re-injection) to materialise. The BGC would undertake the task of rehabilitating 30 existing facilities and two major processing plants in North Rumaila and Khor al Zubair previously operated by the South Gas Co; but, as oil production expands, investment in new capacity is needed to reach the planned annual gas production of 20 bcm. The consortium partners – South Gas Co. (51 per cent); Shell (44 per cent); and Mitsubishi (five per cent) – have also proposed the construction of a US$4bn liquefaction plant, which will make Iraq an LNG exporter with an annual capacity of four million tonnes. However, future LNG exports depend on the availability of surplus gas beyond that required for meeting domestic needs. At the time of writing, there was no news on the Final Investment Decision (FID) by consortium partners on the proposed joint venture in southern Iraq.
An ambitious LNG plan
To capture and monetise flared gas in Basrah Province, Iraq signed a Head of Agreement (HoA) in 2012 with Royal Dutch Shell to create a new joint venture, Basrah Gas Co. (BGC). The 25-year project, costing US$17bn, has a planned output capacity of two billion cubic feet per day by gathering and processing the associated gas from three giant southern fields (Rumaila, Zubair and West Qurna Phase I), much of which is currently flared.
A real potential to export non-associated gas production exists in the north, namely in the Kurdistan Region of Iraq. Turkey provides a vast, proximate export market, with a soaring demand for imported gas, as well as a gateway to southeast Europe and, further, to the European Union (EU) markets. A 2010 report for the European Commission entitled ‘Supplying the EU Natural Gas Market’ identified Iraq as a new source of gas supply to the EU, predicting
“Iraq is still nowhere near achieving its potential, considering the resources that it has” - Raad Alkadiri, senior director in petroleum sector risk at PFC Energy
Building an integrated industry
Iraq’s central aim for the gas sector is to utilise a valuable domestic resource for fuelling economic development, with the power sector a major priority for gas use, followed by the domestic industry. Iraq also aims to become an exporter of natural gas.
IRAQ GAS RESOURCES BY REGIONS AND SUPER-GIANT FIELDS (Billion cubic metres)
Southern Mesopotamian
Proven*
Ultimately
Cumulative
Remaining
reserves
recoverable
production
recoverable
Remaining % of ultimately
end-2011
resources**
end-2011
resources
recoverable resources
2,202
4,298
351
3,947
92%
West Qurna
780
1,139
18
1,121
98%
Rumaila
332
838
288
550
66%
Majnoon
203
388
2
386
99%
Zubair
156
334
39
295
88%
Nahr Umr
193
379
4
375
99%
Central Mesopotamian
179
700
1
700
100%
East Baghdad
126
367
1
367
100%
Northern Zagros Foldbelt
993
2,027
158
1,867
92%
Kirkuk
248
256
154
102
40%
60
906
0
906
100%
Western Desert Total IRAQ
3,435
7,932
510
7,422
94%
Associated
2,558
5,279
505
4,773
90%
876
2,653
5
2,649
100%
Non-associated
* Proven reserves broken down approximately by basin, based on data provided by the Iraqi Ministry of Oil (MoO). ** Ultimate recoverable resources (URR) for associated gas is derived from oil URR & known gas-oil ratios. Sources: USGS; data provided to the IEA by the US Geological Survey and the MoO; IEA databases & analysis.
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Iraq
According to International Energy Agency (IEA) figures, Iraq’s marketed gas production (net of flaring, venting and reinjection) is projected to increase significantly over a 10-year period, from just seven billion cubic metres in 2010 to between 41 and 63 bcm in 2020, and then reaching between 82 and 105 bcm by 2030. These projections, however, depend on Iraq installing the necessary infrastructure to capture and process the rising volumes of associated gas, mainly from the southern oilfields, and successfully developing nonassociated gas fields. Should the IEA projections come to fruition, then natural gas would cease to be a mere byproduct of crude output, as in the past, and become a more pivotal and autonomous part of Iraq’s future energy strategy. “This will require integrated planning from the government to ensure that the production, capture and processing of gas proceed in a coherent way, that processing plants are well-sized and located and that the richer components of the natural gas stream – condensate, liquefied petroleum gas (LPG) and, once there is a market for it, also ethane – are separated and used productively in the national economy,”
Iraq’s central aim for the gas sector is to utilise a valuable domestic resource for fuelling economic development noted the IEA in its Iraq Energy Outlook 2012 report. The growth in gas processing capacity implies that Iraq will become a producer of LPG, which is widely used in the Middle East as a fuel for cooking and heating and, increasingly, also within the petrochemicals sector. From its current position of requiring LPG imports of around 33,000 bpd in 2011, Iraq could become a net exporter by 2016.
Hurdles
The development of non-associated gas resources holds a key to determining Iraq’s prospects for potential gas export. Gas provides an important substitute for oil use in the domestic market, freeing up the
more costly and more easily exportable commodity. There is still considerable uncertainty over the extent to which gas will be used in power generation and industrial uses and how quickly gas flaring will be reduced. Over time, a more market-oriented electricity sector and a higher domestic gas price would provide incentives for private investments in gas for domestic use. It also requires the development of a transport network (ie, pipelines) to the power plants and other industrial facilities that will account for the bulk of Iraq’s gas consumption. Continuous political disputes and general insecurity across the country are obstructing viable plans for developing downstream oil and gas sectors. “Iraq is still nowhere near achieving its potential, considering the resources that it has,” said Raad Alkadiri, senior director in petroleum sector risk at US-based consultancy PFC Energy. The proposed Hydrocarbon Law, first mooted in 2007, to govern contracting and regulations has yet to receive final passage – with little prospects of being passed in 2013. ■
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Basra Oil and Gas Date: 5th-8th December, 2013 Venue: Basra International Fairground
Investors and suppliers
welcome in Basra Immense business opportunities exist in the development of the energy industries in southern Iraq say the organisers of Basra’s fourth international energy event.
There are huge opportunities in Iraq
W
ITH THE SUPPORT of Iraq’s Ministry of Oil the 4th Basra Oil & Gas International Conference & Exhibition will be held from 58 December at the city’s International Fair Ground. Last year’s combined events attracted 13,000 visitors in all. The organisers (contact details below) tell us that this year’s conference and exhibition will focus on the key of oil and gas development issues of the day: exploration geology and geophysics; drilling and well servicing; oil- and gasfield equipment and services; and all aspects of process and engineering design (front-end and detailed) – all for the specific categories of equipment and services listed below. Almost one-third of all exhibitors expected this year will be based here in Iraq; the whole combined event is therefore expected to provide an excellent opportunity for overseas company representatives to 62
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network with key hard-to-reach players on the domestic scene such as State Co for Oil Projects, South Oil Co, South Gas, Iraq Drilling and Missan Oil. The UAE, USA and Turkey are likely to provide the next largest contingents. With the world’s third largest ‘proven’ oil reserves and largely unknown resources of gas, both associated and non-associated, Iraq is certainly, as last year’s Basra conference succinctly claimed, a ‘Hub of future energy.’ Just 23 out of 79 known oil and gas fields are currently in production;
Southern energy fields around Basra in particular offer immense opportunities
‘probable’ reserves of conventional crude alone are reckoned at more than 200bn barrels. Fast-recovering production in August stood at 3.25mn bpd. Probable gas reserves are now of the order of 500 TCF. Development of these huge and immensely valuable resources are obviously the first priority, but Iraq in general and the southern energy fields around Basra in particular offer immense opportunities for investment in and supply of oil and gas production, processing and handling facilities of all types. For example, the whole pipeline transfer system (both internal and export links) is antiquated and completely inadequate for the volumes of raw materials and products that are now beginning to appear. The current refining capacity of ca 600,000 bpd fails to meet the current level of domestic demand, and produces the wrong product mix anyway. As a result around one-quarter of all
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energy products currently consumed in fast-growing Iraq continue to be imported – many of them through this southern port city itself. Modernisation and expansion plans are many, and exist in all sectors, and no less than four brand-new refineries are planned, with private investment opportunities advertised as being available in each one (including a single huge 300kb/d unit nearby).
Modernisation and expansion plans are many The two-day associated conference on “Optimising oil exports” itself, fourth in what has proved to be a very successful and illuminating series, is once again being put together by the local well known and now completely independent energy resources and industries consultant Falah Al-Khawaja. After a long career as a telecommunications specialist and within the Oil Ministry itself the programme he has assembled this year will cover, on the first day: Oil and gas production prospects within Iraq, including a review of exports and exploration activity to date, and including current targets identified; Medium- and long-term world supply and demand considerations through to 2030, including the likely consequences of the USA’s predicted self-reliance; Progress in processing and storage; and local drilling and well servicing constraints.
www.basraoilgas.com The following day’s discussions and panel sessions will focus on commercial aspects of resource development, specifically the management of oil revenues. These sessions will be devoted to: Iraq’s coming integrated energy strategy (Panel session); Technology and training; Aspects of corporate social responsibility; and a Review of the latest industry-standard HSE requirements. Say representatives of this year’s exhibition management team: “We would like to invite all companies to join the 4th Basra Oil & Gas event in order to take advantage of the immense business opportunities that Iraq offers.” ■
For fuller information visit www.basraoilgas.com/info.html or call +90 212 356 0056 (1725) [info@basraoilgas.com]. All associated events are jointly being organised by Pyramids International, M&T Iraq and Expotim International Fair Organizations, Inc Issue 7 2013
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VISIT US AT ADIPEC, ABU DHABI, 10-13 NOVEMBER, UK PAVILION, STAND 8151
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ADIPEC 2013 Date: 10-13 November Venue: Abu Dhab National Exhibition Centre
Delegates converge on
Abu Dhabi again ‘S EE YOU AT ADIPEC’ has become a catchphrase widely heard amongst technical professionals in the mid- and upstream oil and gas industries around the world.
Now held annually in Abu Dhabi, and the largest such gathering anywhere in the Middle East, this is the four-day occasion when scientific and other technical specialists from all over the energyproducing world come to the UAE to hear the best and latest about what’s going on in their own particular fields. ‘To get up to speed about technical developments in the Gulf’ is another term we as regular delegates and exhibitors have heard. For 2013 the inclusive dates are 10-13 November.
Rigid assessment
This year, the 16th successive ADIPEC*, the conferees will have the opportunity to hear from more than 300 of their peers from 33 countries who have won through in a fiercely-fought contest to introduce either a paper or panel presentation that is worthy of such a prestigious occasion. All submissions have been subjected to a process of rigid assessment by well respected professionals from near and far; more than 25 separate industry organisations were involved in the rigorous vetting process this year.
A business conference has been added to an already lavish programme And as usual, a number of attractive new features such as a Business Conference (long overdue given the global popularity of the event amongst commercial representatives, we feel) and a ‘Women in industry’ experience-sharing panel have been added to an already lavish programme which, last time around, attracted more than 4,200 delegates to the Technical conference-hall proceedings alone. In addition, more than 50,000 came through the doors of the associated exhibition of institutions, government and NGO agencies, industry publications and industry product and service suppliers. If previous trends are followed (the whole series started back in 1984) this year’s combined events will be bigger than ever.
Training courses
On a theme of ‘Energy for all in a changing world’ the highly detailed Technical programme alone covers nearly 60 printed-out pages; there will be more than 50 individual Technical Sessions incorporated within it; see the website for timings and content, and for details of the presenters themselves.
www.adipec.com Separate simultaneous up-/mid-stream industry training courses on offer this year on the 9th will cover Oil field data management, Introductory geomechanics, Characterisation and modelling of naturally fractured reservoirs, and Fundamentals of gas compressors in specifically field applications.
Perspective
Optional field visits to a nearby gas processing plant and the onshore Al-Dabb’iya field are also on offer, to put all the talking and demonstration into perspective. The associated Business Conference (10-11 November only) has the introductory combined themes of ‘Strategic alliances’ and ‘Global oil and gas frontiers”,’ in the capable hands of the chairman of this year’s ADIPEC events as a whole, Mr Mohammed A Sahoo AlSuwaidi of ADNOC’s Gas Directorate.
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A number of the industry’s really big names from overseas including Abdelhamid Zerguine from Sonatrach, Bob Dudley of BP, Helge Lund of Statoil and Igo Sechin of Rosneft will be behind the rostrum at this launch event which promises to cover energy security, product monetisation and workforce maintenance issues; again see the website listed below for the full incorporated programme.
Social events
A series of Industry ‘Excellence in Energy’ Awards is again on offer this year, covering such categories (six in all) as Best project, Best innovation, Empowerment of women demonstration, and Young engineer. These will be presented at one of the evening social events held nearby in the city. The ‘Young ADIPEC’ section of the event, in partnership with the Ministry of Culture & Youth as well as international industry players such as General Electric and Technip, has been designed to attract potential trainees and recruits of an even younger i.e. secondaryschool age. ADIPEC is once again taking place under the patronage of the President of the UAE and all individual events are being supported by the Federation’s Ministry of Energy along with the national energy supply business ADNOC and the local Chamber of Commerce. Amongst a long list the biggest sponsors this year include BP, Rosneft, Shell, Total, and Occidental Petroleum. ■
*Abu Dhabi International Petroleum Exhibition & Conference For more information visit www.adipec.com, call Operations Director Julie Allen on +971 4 438 0355 or e-mail adipec@dmgeventsme.com
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This year’s combined events will be bigger than ever. Thousands of visitors are expected again this year
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An initiative to
inspire students This year’s ADIPEC will see the launch of an initiative to inspire students to pursue a career in the oil and gas industry.
T
HE ABU DHABI International Petroleum Exhibition and Conference (ADIPEC) is set to launch comprehensive programme designed to inspire a generation of young people across the UAE to pursue a career in the gas and oil industry. Under the patronage of His Highness Sheikh Nahyan bin Mubarak Al Nahyan, Minister of Culture, Youth and Community, and supported by Abu Dhabi Education Council, Young ADIPEC will involve a series of youth engagement activities up to and beyond ADIPEC that enable young people across the country to connect with the gas and oil industry and better understand the opportunities it offers. The initiative will address the growing shortfall of young people entering the industry, which poses a threat to the future success of the sector, particularly during a critical time of development and evolution. According to research from the Petroleum Institute, nearly 50 per cent of the current energy workforce is set to retire in the next 10 years.
Vital
“The gas and oil industry grows in its importance year on year as economic growth creates surge in energy demand across the world and crucially within the Middle East,” said Mohammed A. Sahoo AlSuwaidi, director, Gas Directorate – ADNOC and Chairman – ADIPEC 2013 Conference. He added: “It is vital that the industry takes collective responsibility to inspire and nurture our youth to pursue careers within the sector, safeguard our economic future and ensure energy security. Young ADIPEC is designed to facilitate that process as an initiative of critical importance to the future of the gas and oil industry both regionally and internationally.” 70
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Looking for a career?
It is vital that the industry takes collective responsibility to inspire and nurture our youth to pursue careers within the sector The initiative will begin with the selection of 200 11-18 year-old students from schools across Abu Dhabi and the Western Region. The students will enjoy trips to oilfield sites, training centres and gas tool workshops in Abu Dhabi. Throughout the excursion, video diaries will be recorded and eventually displayed on the interactive photo wall at the experience centre at ADIPEC. Young ADIPEC will also include live activation on Abu Dhabi Corniche during ‘Yasalam’ – a series of pre and post-race events across the capital. The Young ADIPEC activation will feature a fully electric car designed and built by local students, in collaboration with Shell – demonstrating the exciting and futuristic opportunities the energy business offers.
The initiative also features social media competitions and interactive-Young ADIPEC zone during the event itself, which will include interactive video games, animated films, a treasure hunt and a career guidance cell. It will also host a museum and an experience zone, allowing students to gain an insight into the workings of the gas and oil industry and a Petroleum Institute zone, giving young people clear guidance on the education path.
Shortage
AlSuwaidi added: “We face a worrying shortage of skilled young professionals and in a region that is so important to the global hydrocarbon industry it is imperative that steps to reverse the trend are taken.” Supported by ADNOC, GE Oil and Gas, Total, Shell, Exxon Mobile, Partex Oil and Gas and Technip, Young ADIPEC is just one of a raft of new features launched at this year’s event, which will showcase an expanded technical conference, a brand new business conference and a critical look at the role of women in the oil and gas industry. ■
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A wide range of safety interlocks
Unique coupling
LOCATED ON STAND #8233, SFC’s EasiDrive Smith Flow Control (SFC) will demonstrate its headline products at ADIPEC, in addition to its wide range of safety interlocks. On display will be SFC’s portable valve actuator, EasiDrive. Using EasiDrive, an operator can easily operate multiple valves, avoiding fatigue and injury risk. EasiDrive is apparently especially effective on valves that require many turns, or valves that are difficult to operate due to high torque or challenging climate conditions. FlexiDrive is SFC’s remote valve operating system that the company states allows users to operate valves from a safe distance of up to 30m. It can be applied to any conventional wheel-operated device to make it constantly accessible and safe. SFC will also be showcasing its PSV system which it says ensures maintenance procedures on safety relief systems operate in the defined, safe sequence. SFC is a UK firm which specialises in the field of mechanical valve control equipment. This includes: procedural control using mechanical valve interlocks and activity management systems, EasiDrive portable valve actuators, FlexiDrive mechanical valve linkage systems for remote and/or simultaneous operation.
COMBIFLOAT CLAIMS THAT it has been very successful in meeting the needs of its clients by resolving their marine challenges. The company says its long history and extensive experience have contributed to its reputation for the highest quality workmanship and a fast and reliable service. Flexifloat Systems B.V. is the exclusive supplier of the modular Combifloat® pontoons. A wide variety of clients in the offshore and marine construction industry are already using this flexible modular floating or elevating construction system, eminently suitable for coastal and inland waters, says the manufacturer. By means of a simple coupling and locking system the units can be assembled to any project specific configuration. The coupling system is easy to handle and strong enough to be used in Self Elevating Platforms with deck loads up to 1,000 MT. Equipment requirements for marine operations vary with local conditions and with the type of job to be performed. For every job, there is the challenge of finding the right equipment. With this mind, the Combifloat modular pontoon was designed.
Stand 8233 (Hall 8)
Stand 12242B (Hall 12)
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Alliance tackles shale resource challenges IT IS NOW a year since CGG and Baker Hughes announced that they would enter into a collaborative relationship that could redefine shale reservoir exploitation. Since then CGG has acquired Fugro’s Geoscience division and developed a stronger geoscience focus. We review the progress of the alliance from the perspective of Sophie Zurquiyah, EVP of CGG’s Geology, Geophysics & Reservoir Division and Tim Adams, Vice President of Business Development for Baker Hughes. “The landscape of CGG has changed significantly in the last year. We have seen the influx of a huge amount of geoscience expertise from Fugro Geoscience which has bolstered our product and service offering and made a significant contribution to our shale alliance with Baker Hughes. At the same time we have seen a growing acceptance in the industry that more geoscience can improve success in the development of shale resources,” says Zurquiyah. Industry estimates indicate that approximately 70 per cent of unconventional wells in the U.S. do not reach their production targets and 60 per cent of all fracture stages are ineffective. With typical well costs in the range of US$6-8mn, this is a significant risk. The alliance is focusing attention on key stages in the E&P workflow where geoscience can make a real difference. The concept is to use a broad range of geoscience data to continuously improve reservoir knowledge throughout the life of the field. This approach will allow shale operators to make better informed decisions to: • Increase production and ultimate reserve recovery • Reduce exploration and development risk • Increase operational efficiency • Improve financial performance of the asset So what does the alliance have to offer and what has been achieved in the first 12 months? “In terms of demonstrating the benefits of the alliance and an integrated approach for
Integrated interpretation of calibrated seismic attributes highlights areas with the highest production potential (courtesy of CGG). shale, we have been working on two pilot projects, which are providing us with encouraging results. They are allowing us to demonstrate the petrophysical and geomechanical calibration of seismic attributes using borehole information (cores, cuttings and logs) to build more accurate predictive models. They have also given us the opportunity to explore the role of microseismic data in validating and calibrating reservoir models,” says Adams. There are several objectives for the alliance across the E&P workflow. At the exploration and new ventures stage, CGG’s rich multi-disciplinary multi-client data library of geological reports, gravity & magnetic data, high-quality 3D seismic data and basin prospectivity studies can provide a competitive edge by helping to identify the most prospective acreage. When it comes to drilling patterns, well placement and the hunt for so-called sweet spots, a thorough understanding of the factors controlling reservoir quality and production potential are required. Nearwellbore mineralogy, lithology, rock strength, and natural fracture data derived from LWD, coring, and wireline logging services from Baker Hughes and quantitative rock
mineralogy from CGG provide the ground truths for a reservoir model. The integrated interpretation of this information and the seismic data allows the development of meaningful predictive models to guide well placement and trajectory. To ensure maximum reservoir contact for lateral sections the alliance employs the Baker Hughes RNS™ Reservoir Navigation Services, which can be complemented by CGG’s onsite geological services. With studies showing that only 40 per cent of fracture stages effectively contribute to production, geoscience also has a role to play in enabling the best well performance. With Baker Hughes’ MFrac™ fracture simulation and modelling software and StarTrak™ LWD technology, coupled with CGG’s RoqSCAN™ wellsite mineralogical analysis from Robertson, fracture stage placement and parameters can be optimised. By closing the loop with microseismic monitoring and production logging interpretation it is possible to validate and update the reservoir model, and is part of the process of continuously improving reservoir knowledge to maximise production.
Stand 1434 (Hall 1)
Optimising productivity and well economics HALLIBURTON RECENTLY INTRODUCED its CYPHERSM Seismic-to-Stimulation service, a collaborative workflow that integrates geoscience, reservoir, drilling and completion engineering to allow operators to better predict and produce unconventional reserves. The service is supported by a breakthrough technology suite using an iterative process www.halliburton.com that identifies the best well placement and stimulation designs, critical parameters to the total well cost and ultimate production. Operators have discovered that developing shale or other tight reservoirs requires special treatment. The processes and technologies that 74
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have worked for many years in conventional reservoirs often are not adequate for the complexities of unconventional reservoirs. Shale and tight reservoirs can contain multiple sweet spots mixed with non-productive rock. Misplaced fracturing zones or missed production opportunities can result in expensive wells and sub-optimised well economics. Cumulative production can vary widely in a field, depending on well placement.
Stand 7222 (Hall 7)
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Sharper resolution detects issues instantly FLUKE CORPORATION RECENTLY introduced the Fluke® VT04 Visual IR Thermometer, the latest troubleshooting tool with built-in digital camera and thermal heat map overlay that the company says bridges the gap between traditional IR thermometers and infrared cameras. Building on the popular Fluke VT02, the VT04 adds PyroBlend™ Plus with a four-times sharper resolution than the VT02 and automatic alarm features. Fluke claim it is the ideal frontline troubleshooting tool for electrical, industrial maintenance, HVAC/R, and automotive applications. The ultra-compact Fluke VT04 is fully automatic with built-in intelligence, so issues can be detected instantly with no training required. “Compact and affordable enough to outfit an entire team, the VT02 and VT04 are designed to be with you at all times as a frontline troubleshooting tool in
the Middle East,” said Fluke business unit manager, Jay Choi. Fluke Corporation is the world leader in the manufacture, distribution and service of electronic test tools and software. From industrial electronic installation, maintenance and service, to precision measurement and quality control, Fluke says its tools help keep business and industry around the globe up and running. Typical customers and users include technicians, engineers, metrologists, medical-device manufacturers, and computer network professionals — people who stake their reputations on their tools, and use tools to help extend their personal power and abilities.
Stand 9452 (Hall 9)
Intelligent completions TENDEKA, THE PROVIDER of completions systems and services to the upstream oil and gas industry announced the launch of the SigNet Wireless Intelligent Completion solution to help operators maximise output from new and existing wells. The launch of SigNet enhances the company’s wireless offering with the introduction of an interval control valve (ICV) as well as downhole power generation capability, resulting in extended battery life. SigNet also retains the
The launch of SigNet enhances the company’s wireless offering with the introduction of an interval control valve (ICV)
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proven monitoring capability of Tendeka’s Wireless PT Gauge. Commenting on the launch of the new product Ken Miller, Tendeka’s VP for North and South America, said: “We have developed the SigNet Wireless Intelligence Completion Technology in response to market demand. The need to maximise production from new and complex reservoirs as well as increasing recovery rates from mature fields has led to an increase in the deployment of downhole monitoring and control systems. “Today’s intelligent completions must be linked back to the surface and to date this is generally achieved via multiple hydraulic lines, electric control line or a combination of the two. Wireless solutions open up new applications, providing solutions for multilateral wells, existing wellbores and open-hole sections. Our SigNet Wireless Intelligent Completion Technology, which can be retrofitted to existing well architecture, is an innovative, cable free combination of measurement, inflow control and downhole power generation which truly enables direct in-lateral flow control for the first time.” Water breakthrough, large differential pressures between zones and water and gas capacity management are problems that are commonly found in mature areas. As such, downhole flow control can have a significant and immediate impact. Annabel Green, Tendeka’s Product Line Director for Wireless Technologies, added: “Our initial design configurations for wireless ICVs are focussed on mature fields and we expect the first of the new SIGNET Wireless Completions Systems to be installed during Q1 of 2014”.
Stand 12184 (Hall 12)
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Fiscal and custody transfer metering ALDERLEY, A MARKET leader in liquid and gas metering and produced water treatment packages and hydraulic control systems, will be exhibiting at the 16th ADIPEC exhibition. Alderley will be highlighting their experience in supplying fiscal and custody transfer metering systems, metering control and supervisory systems and produced water treatment solutions to the oil and gas industry. This experience gained from working in the Middle East for the past 16 years has enabled Alderley to use their knowledge of technology and local standards to deliver technical excellence throughout their projects. On the stand Alderley will be promoting their series of metering training courses that are now taking place at their new expanded facilities in Jebel Ali Free Zone, Dubai and will be discussing new projects such as the one secured earlier in the year to deliver 22 gas and liquid metering skids for the KOC/KNPC Telemetry Project in Kuwait. The process technologies team will be highlighting market leading separation technologies which are continuously being improved to achieve even greater separation
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of the more problematic droplets and particles along with demonstrating their technical know-how of providing solutions such as the recent Maersk Oil Qatar Gas Flotation Package that is designed to treat Produced Water with an inlet oil concentration of up to 3000 ppm(v) to achieve a guaranteed outlet of < 20 ppm(v) www.alderley.com using Deoiling Hydrocyclones and Gas Flotation. Eric Maddock, Group Business Development Director, says, “We are looking forward to attending ADIPEC for the fifth time. It is the largest event for the industry in the Middle East and the perfect exhibition to keep our Middle East and International customers updated on Alderley’s projects and growing financial success which has seen us secure USD$96mn worth of orders in the past 12 months. It also gives us the opportunity to spend time with customers to
understand their needs for the future.” Alderley is a multi-disciplined engineering company operating in the oil, gas and petrochemical industries producing effective and efficient solutions for the metering, processing, treatment and control of hydrocarbon products. Alderley has been manufacturing oilfield metering equipment since 1959 and has supplied more than 750 systems to more than 50 countries.
Stand 8235 (Hall 8)
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ProSafe(R) improvements noted YOKOGAWA ELECTRIC CORPORATION has launched an enhanced version of the ProSafe(R)-RS safety instrumented system and the addition of a new function to the DPharp EJX multivariable transmitter. The new ProSafe-RS version, R3.02.10, offers improved functions for upstream oil and gas, which is one of Yokogawaâ&#x20AC;&#x2122;s core markets. The DPharp EJX multivariable transmitter has been enhanced to improve connectivity with ProSafe-RS. In upstream oil and gas processes, there is an ever-pressing need to prevent accidents and protect the environment. Accordingly, there is a growing demand for safety instrumented systems that can detect abnormal conditions and safely initiate emergency shutdowns. However, wells and pipelines are typically distributed over a wide area and often have limited space for the installation of equipment. To improve operational
ProSafe(R)-RS safety instrumented system
efficiency and reduce hardware costs, there is a need to consolidate the functions performed by control and safety instrumented systems. In response to these needs, Yokogawa is releasing a
new version of the ProSafe-RS safety instrumented system and has enhanced the DPharp EJX multivariable transmitter.
Stand 11350 (Hall 11)
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Global gas usage is up but the pace of growth has slowed. MENA’s attractions as an investment location remain strong.
The rate of global gas consumption is falling
Because gas
matters
E
NERGY DATA COMPILED by BP* shows that the rate of growth of global gas consumption is falling. But the world’s reliance on conventional supplies from North Africa and the Gulf remains a key feature of a vitally important business nevertheless. Part of the reason for the rise in all-forms energy consumption slowing to just plus-1.8 per cent last year was that most prices remained high, despite the increase in diversity of sources, including unconventional gas. Huge low-cost US shale supplies were of course the principal new feature impacting on the business, but any price-lowering effect from this elsewhere, including here in the Gulf where power generation is so gas-dependent, remains to be seen. However, local suppliers, dealing in the conventional piped and liquefied forms of what is still the world’s favourite fuel, need to be aware that regional trends in gas use are continuing to diverge significantly. Natural gas provided just under one-quarter of the world’s traded energy last year, the multinational energy company says. All the net growth in global all-forms consumption
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took place in the loose group of economies which include the Gulf states; in fact, China and India alone accounted for nearly 90 per cent. OECD (first-generation industrialised country) consumption dropped by 1.2 per cent while that of the emerging economies grew by 4.2 points.
Elsewhere, consumption-wise there were some major individual changes seen in 2012 The net result was that both consumption (and therefore output) reached record levels for all hydrocarbons in 2012. So prices for natural gas rose with oil in both Europe and Asia despite the growing impact of all that low-cost hydraulically-fractured fuel being used in North America, which continues to remain (almost) entirely in physical terms within that fortunate continent. So far, as far as we know, Federal approval has been granted for the
conversion of only a handful of existing LNG import terminals into facilities that can export and thereby link the USA to the much more pricey world market. Several others are believed to be in the planning pipeline, and the WTO is thought to be watching the situation for progress on this key issue closely. The bottom line is therefore that the outlook for MENA-based suppliers in general continues to remain excellent despite the USA’s shale-gas windfall. However, the timehonoured index-linking of international gas and oil prices may be coming under threat as the size of the resource base expands. After their 2nd Summit Meeting in Moscow in July the Gas Exporting Countries Forum said they intended to “Uphold the fundamental role of long-term gas contracts and continue to support gas pricing based on oil/oil products indexation.” Headquartered here in Doha the GECF includes Algeria, Egypt and Libya in North Africa as adherents. Gulf membership includes Iran, Oman, Qatar and the UAE. In detail, global use of gas grew by 2.2 per cent in 2012, with North America and above all China and Japan heading the continuing upward trend. But at the same
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time any increase in international trade, by both pipeline and deepsea gas carrier, was exceptionally weak at just 0.1 per cent year-on-year. And global business in liquefied natural gas in volume terms fell for the very first time ever, by 0.9 per cent. “LNG’s share of global gas trade declined slightly to 31.7 per cent,” the BP report says; a big drop in imports by European countries like the UK being almost entirely responsible. The massive increase in global gas resources has filled the media headlines throughout the year, almost entirely because of unconventional activity in general and the expected impact of the newly-commercialised technology of hydraulic fracturing in particular. However, the scale of exploitable reserves is a different matter. So it is only in North America that shale gas can really be fully and accurately accounted for in the equation as yet; elsewhere it remains largely a case of “who knows and who allows?” And if this new form of gas (which will bring necessary onshore processing adaptations and other costs with it) is found in the sort of quantities that are being talked about now (much more than doubling world reserves) it is anything but certain how much can be actually successfully developed commercially. Like tar sands development, hydraulic fracturing does not come cheap. Therefore outside of North America the impact of the so-called 'fracking revolution' remains to be seen even though so much is being heard about it right now. But potential gas exporters without long-term supply contracts in the bag do need to keep their eyes on the ball. On the global production front the main news has been the USA’s 4.7 per cent increase last year; globally growth was a mere 1.9 per cent. Some other countries did even better, such as Saudi Arabia (11.1 per cent, mostly conventional), and back-on-track Libya. In all-Africa’s biggest single gas-producing nation (Algeria) output actually fell. In terms of consumption automobiles and trucks are already reported to be running around in many gas-blessed US states with new-form compressed natural gas in their tanks. Along with gaspowered container ships this is going to be a major growth trend in the world’s automotive markets quite soon as better diesels and other developments row back the recent advances in battery technologies. Elsewhere, consumption-wise there were some major individual changes seen in 2012, most of which (such as in South America) have not influenced business here in MENA at all. However, the 11point increase in gas processing for local use in Algeria did surprise some, although it seems to be a logical commercial response to the general weakening in volume terms of the gas market in Europe. Due to high prices gas use in this nearby region (including Eurasia), the world’s largest consuming group, was down by 2.3 per cent. Japan’s 10.3 per cent increase was inevitably a standalone case, almost entirely due to the fall in output of nuclear-generated electricity. LNG traders dealing with Asia did particularly well out of this development, with supplies from Qatar rising by nearly 35 per cent. Other Gulf states benefited from the booming LNG trade with other Far Eastern countries too. One of the unavoidable features of the gas market is that it remains very high cost, both to develop initially and to supply on an ongoing basis after that. In Qatar-pursuing Australia development costs are believed to be rising fastest of all, and this is providing opportunities for MENA’s traditional suppliers, and to the potential nimble newcomers like Angola in Africa who have the resources of all those handy oil-/gasfield service companies (and in some cases Chinese NOCs) to rely on. But gas has become increasingly important to the supermajors too, and the competition is going to be tough if the major consuming groups do manage to break that long-assumed linkage with the international cost of oil. ■
* ‘BP Statistical Review of World Energy June 2013’; www.bp.com/statisticalreview
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A benchmark for
innovation Mohammed A. Sahoo AlSuwaidi, director, gas directorate - ADNOC, Chairman – ADIPEC 2013 Conference, spoke to Oil Review about this year’s first annual event. What does the new edition of the annual Abu Dhabi International Petroleum Exhibition and Conference (ADIPEC) have in store? ADIPEC as a platform has been around since 1984. Since then, this premium event for the petroleum industry has continued to evolve and adapt itself to industry dynamics to benefit both the sector as well as its professionals in the best way possible. With some great milestones achieved in 2012, the edition this year will showcase new developments such as an award category for women in the industry to acknowledge organisations with a proactive approach to female industry empowerment. We also have a youth engagement initiative called Young ADIPEC. Against the backdrop of a potential skills shortfall in the gas and oil sector, we will dedicate time and expertise to inspiring a generation of young people, particularly UAE nationals to pursue a future in hydrocarbons. In addition to that, ADIPEC is becoming an annual event for the first time in its history. Can you elaborate on your reasons for doing so? The regional and global energy landscape is evolving. The challenges we face in ensuring our energy security as an international community are becoming more complex - a reason why the event this year has been themed ‘Energy for all in a Changing World’. Exploration is becoming riskier and more expensive and while proven reserves of oil and gas are plentiful – the exponential growth in energy consumption is compelling the industry to realign its course. In order to remain agile and proactive, and benefit from the latest technology and shared 82
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Mohammed A Sahoo AlSuwaidi experiences, the entire sector must engage in regular and frequent dialogue. For this reason, it is imperative that platforms such as ADIPEC are held annually. What does energy for all in a changing world mean? The global energy landscape is entering a transitional phase. United States, Saudi Arabia, Kuwait, East Africa, Australia and China are all unearthing new gas resources. And while oil has been the lifeblood of economic growth in the region, the diversification of our energy mix is now the only way to ensure long- term prosperity and energy security. The increasingly critical nature of gas and the role it plays in delivering power, potable water and economic prosperity to this region is becoming more critical than ever. New explorations in oil are gradually becoming rare and expensive, shifting the industry’s focus towards gas. Extending the gas value chain, and exploring the future viability of gas as a fuel and feedstock will be featured far more prominently than at the previous year’s event.
What role does ADIPEC play in advancing the global hydrocarbon industry? ADIPEC is a platform that promotes dialogue and interaction. By attracting the biggest global players from the oil and gas sector, ADIPEC is at the cutting edge of technological advancement, and business opportunity within the industry. As an incubator of knowledge transfer and a forum for debate, ADIPEC enables the industry to collectively plot its way through challenges and ensure continued growth and sustainability. On the subject of planning for the future, what role do ‘traditional’ oil and gas companies play in future energy? The world’s major oil and gas companies are a vital part of the solution to sustainable future energy. With exponential rise in energy demands over the next decade, the future of energy is a balanced mix of oil, gas, nuclear and renewables. The energy industry as a whole will need to work collaboratively to ensure a smooth transition from an oil-driven economy to a more diversified and sustainable one that
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integrates new peripherals. Major oil companies are already adapting to the evolving energy landscape and working collectively with new energy players to find lasting solutions to critical issues. The UAE is spearheading the gas revolution. How is ADNOC contributing to Abu Dhabi’s gas strategy? All indications are that natural gas is set to play an ever greater role in the global energy mix, sparking the thought that gas could take the place of oil in the future. It is possible that gas could account for up to 25 per cent of global primary energy demand by 2035 – overtaking coal to complement oil as the world’s dominant energy source. The growth of gas exploration and development projects in this region appears to substantiate this fact. Currently, our gas projects are worth around US$73bn in the tendering phase, across the countries of the Gulf. Abu Dhabi accounts for over US$25bn of this value. This demonstrates the importance of gas to the UAE as part of that diversified energy mix alongside oil, nuclear fuel and renewables. It also reflects a global shift towards gas as a primary energy source. Established in 2012 to guide and drive ADNOC’s gas activities, the ADNOC Gas Directorate is responsible for managing new gas development projects and overseeing the gas related activities of the ADNOC Group of Companies. Together with our partners, this Directorate has a major role to play in achieving the objectives of the Abu Dhabi Economic Vision 2030. Against a backdrop of increased local demand for power, how will gas play a part in the energy mix? Abu Dhabi is investing in major gas expansion initiatives like the Integrated Gas Development (IGD) project to meet increasing domestic demand. While we export volumes of LNG, our gas processing capacity will also continue to increase to meet rising domestic demand. At present, gas is the primary fuel used in power generation and sea water desalination plants in the UAE, and will remain so for the foreseeable future. Our long-term forecasts show that even with the full introduction of nuclear fuel and expansion of our renewables programme, more than half of the energy fed to utilities will continue to be derived from natural gas. With this in mind, ADNOC will soon launch a raft of new initiatives to exploit undeveloped gas reserves. This is complemented by the groundbreaking work that is being done by Dolphin Energy and the Emirates LNG Company, projected to be launched in the near future. We are also in active discussions to explore Abu Dhabi’s potential with regard to conventional and nonconventional energy resources. ■ 84
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With experience spanning over a decade in workover and oil well drilling services, Nordic Energy aims to be the company of choice for clients in the Middle East and North Africa. We have adopted international standards and practices in drilling applications and have developed our own concept known as the drilling and work over rig (DWO), which allows a rig-up time of six to eight hours, with a tripping speed of up to 4000 ft per hour in live wells. The reputation of our major shareholder, The Energy House Holding Company KSCC, that owns a 93.75 per cent share in Nordic Energy, adds to our competitive advantage and network in the regional markets. With a capitalisation of US$300M, The Energy House Holding Company is a subsidiary of the investment firm Development Enterprise Holding, which is owned by Kuwait Finance House.
Nordic Energy FZCo A Subsidiary of The Energy House Holding Company Dubai Investment Park 1, P.O. Box 93086, Dubai Tel. No: +9714-8840604 Fax No: +9714-8847704 Email: info@nordicgulf.com Web: www.nordicgulf.com
Services provided by NORDIC ENERGY
Drilling & Work Over Snubbing Coil Tubing Thru Tubing Intervention Fishing & Remedial Services Plug & Abandon Services Emergency Response Risk Management Hot Tapping Gate Valve Drilling Freeze Services Well Control
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Head protection range from JSP JSP WILL BE exhibiting its latest range of innovative above-the-neck personal protective equipment (PPE) at ADIPEC this year. New to the market is JSP Check, a unique online verification system, available at www.jspcheck.com. JSP says it is the first PPE manufacturer to offer this exciting new tool, which enables quick and straightforward tracing and validation of its products and their DNA, so giving users complete confidence in the origin and quality of their PPE. At this year’s show, JSP will be displaying the full breakthrough Evolution (EVO) series of industrial head protection JSP’s new range of PPE can be seen on their stand designed specifically to address different high, medium and low risk environments. JSP will also be exhibiting a number of its respirators on the market and is incorporated innovative respiratory products, including its into JSP’s new Typhoon disposable masks range. award-winning FilterSpec and FilterSpec Pro, It is also used on the new Force 8 half mask, which combine eye (safety specs or goggle) and which fits a wide range of face profiles and can respiratory (FMP3 or FMP2) protection in one be quickly broken down to its component parts integrated PPE unit, and the Powercap Active for cleaning and re-sterilising. powered respirator with full face protection. JSP’s new unique Typhoon™ valve system gives JSP will be demonstrating live testing of its the most efficient exhale performance of products on Stand 1831 (Hall 8)
Multiphase simulator KONGSBERG OIL & Gas Technologies AS (KOGT), announced the release of LedaFlow® 1.4, the new transient multiphase simulator for wells and pipelines. Continuing KOGT’s commitment to providing greater detail and accuracy in multiphase simulation in the Oil and Gas industry, the latest release of LedaFlow contains significant additions and improvements that enable flow assurance engineers to operate faster and more efficiently. KOGWith LedaFlow 1.4, speed increases of up to 4 times can be seen in network cases using multi-CPU capabilities, shaping the LedaFlow solution into a more productive tool for all engineering challenges. LedaFlow has been enhanced with a number of new features designed to improve operating procedures. Release 1.4 includes the ability to plot hydrate margins which helps to mitigate potential loss of production. Additional features include user-defined closure laws defining the relationships for friction and entrainment and the ability for trend loggers to efficiently record high data frequency at selected locations.
Stand 5244 (Hall 5)
Technical echnical excellence excellence: e: delivered delivered
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Optimising water management
for fracturing fluids The world struggles with both decreasing fresh water resources and the increasing and varied demands on those resources. Paul D. Lord, Daniel Shannon, and James Welch fromn Halliburton explain.
M
ANAGING WATER AS a valuable community resource as well as a critical raw material in oil and gas field operations, such as fracturing, requires increasing attention from the oil and gas industry. Water management techniques, stakeholder initiatives, and environmental awareness are coalescing into a methodology to achieve and maintain business practices that meet rational “sustainability objectives” while concurrently maintaining well productivity.
The Path
Water management can be divided into two categories: • Logistics - Managing the global, regional, and intensely local inventories of fresh water. • Use-Related Challenges - Applying innovative technologies to overcome the challenges that the physico-chemistry of water pose to the industry’s operational needs.
Logistics
Global - The ability to reduce and recycle produced water and minimise fresh water use can improve operator profitability and contribute to water conservation. Globally, oil wells produce approximately 220mn BWPD (barrels of water per day), roughly three barrels of water for every barrel of oil. In older fields, the water "cut," or ratio of water-to-oil, can be 95 per cent or higher. Managing this produced water is a key objective and challenge for operators. At the same time, oil and gas operators need water for operations. The economic production of unconventional oil and gas 88
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Figure 1: EC process resources requires significant amounts of water for well stimulation treatments. In North America, an estimated 14mn BWPD is used to increase well productivity in unconventional gas. Thermal enhanced oil recovery (EOR), which requires steam for the improved recovery of heavy oil, uses another half million BWPD. Secondary recovery using
Water processing must be an integral part of the fracturing process
waterfloods for conventional oil uses another million BWPD. Thus, finding and transporting sufficient water for operations is a challenging prospect. Regional - The quantities of fresh water available in a particular region can be affected by several issues, such as how much total fresh water is available per capita, how much the industry consumes in a given period, and what direction the industry must take in terms of recovery, recycling, and reuse. Water chemistry can be adjusted to fit particular uses, but sustainability objectives dictate that specific-use quality windows be clearly defined and processing is limited to only what is necessary to meet those requirements.
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Desander Desilter Scomi Oiltools, a leading global product and service provider of; • Drilling Waste Management Services • Solids Control Equipment • Filtration Services • Drilling Fluids • Production Chemicals operational performance, minimise and manage your waste streams and provide for network of skilled, technically competent engineering and management personnel. Whether you require individual products or integrated services; we offer a tailored, catalyse your business performance. Scomi Oiltools – Realising Potential
Scomi Oiltools (Cayman) Ltd
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However, as fresh water becomes increasingly scarce, the focus must turn to changing the parameters of the quality window. When re-using water for fracturing, changing the fracturing fluid chemistry is critical for establishing a sustainable water management well, field, and regional profile. By altering the fracturing fluid chemistry to accommodate the use of impaired waters, the industry can exit the high-quality water cycle and substantively reduce the regional impact of operations. Potential water sources evolve from municipal, lake, or river water (high-quality water cycle) to the collection of impaired waters, such as industrial effluent, flowback, and produced waters (at 100 per cent) or other highly saline or otherwise contaminated inventories not especially useful for regional population needs. Intensely Local - At the well pad, water management is an inventory management function. However, as applied treatment science improves, it becomes the management of water quality to meet immediate operational needs. As the approach to field development advances, particularly in locations outside North America, water plans for new fields become increasingly sophisticated. In the early development of unconventional resource plays, water was addressed predominantly at the well level (i.e., what is required immediately at the location).
Managing this produced water is a key objective and challenge for operatorsâ&#x20AC;?
www.halliburton.com Since then, well field development has matured, identifying water logistics as a critical supply chain issue that requires careful planning and attention to particular processing requirements throughout the life of the field. Water management e-tools are increasingly popular, as are the incorporation of technical advancements in fracturing fluid chemistry
Sulzer Pumps Your Partner in the Middle East The Heart of Your Process
Sulzer Pumps is a world leader in the supply of pumping systems for the Oil and Gas industry and recognized globally for the quality and high standard of our products. With our extensive Customer Support Services network we are close to our customers. Customers ZLOO Ć&#x201E;QG UHOLDEOH DQG VXSSRUW LQ RXU 6HUYLFH &HQters in Saudi Arabia and in the United Arab Emirates.
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Our local specialists have a profound knowledge of pumps used in oil production, UHĆ&#x201E;QLQJ DQG SRZHU JHQHUDWLRQ DSSOLFDWLRQV Skilled field personnel supports you for on-site service, overhauls, installation and commissioning, machinery diagnostics and troubleshooting.
Abu Dhabi Service Centre, UAE PO Box 915, Ali & Sons Business Centre Umm Al Nar, Al Ain Road 3KRQH Al-Khobar Service Centre, Saudi Arabia 32 %R[ $O .KREDU 3KRQH service-me@sulzer.com www.sulzer.com
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and targeted water processing. These sophisticated tools use linear programing functions to determine the lowest laid in water cost. Each water source is assigned attributes as a function of cost, quality, and volume. The solution set is further enhanced with storage and disposal features. An excellent example would be the production of a crosslinked-gel fracturing fluid from 100 per cent Bakken produced water with 25K+ mg/l of Ca, 200+ mg/l of boron, Fe at 100+ mg/l, and total dissolved solids (TDS) at >250,000, using only minimal water processing (i.e., no desalination). Use-Related Challenges - The use of water of any quality presents challenges, the nature and intensity of which are determined based on the concentration and assay of the compounds in the water, the operating conditions of the selected use, and the operating discipline applied. Sustainability and responsibility drives the merger of water conservation with unconventional resource development, forcing technological evolution to rise to a greater metric. Water processing must be an integral part of the fracturing process, with each technology used becoming a variable. In the past, fracturing fluid construction was set as
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Water management e-tools are increasingly popular” a constant, which required water approaching potable or industrial-use quality. The resulting fresh water draw and/or tonnes of process residuals created undue hyper-local impacts to the water source. By allowing modification of the fracturing fluid recipe, water processing can be precisely targeted. Specifically problematic compounds that might inhibit fracturing fluid performance are selected for removal. These are generally suspended solids, dissolved iron, and hydrocarbons. Electrocoagulation (EC) is perfectly suited for providing minimally processed water that is tailored precisely for fracturing fluid construction. EC is tolerant of major swings in influent quality, which are not entirely rare events in the operating environment. Even with a variable influent quality, EC produces a consistent quality effluent, protecting the blender from operating variability.
EC technology brief key characteristics include the following: • Extreme feed quality tolerance • Consistent product water quality • Consistent and reliable throughput • Less waste than more complex processes
Basic Technology
The process (Fig. 1) works through dissolution of elemental Al and/or Fe through an applied current. The cationic, dissolved metals neutralize the negatively charged particles, facilitating agglomeration. Separation velocity is a function of the square of the particle size, so rapid separation is affected by the process. The electric current also destabilizes Fe and resolves tough emulsions. A product water characterized by <10 NTUs of turbidity, less than 10 mg/l of total petroleum hydrocarbons (TPH), and <5 mg/l of Fe is consistently provided. By combining sophisticated fracturing fluid science with EC processed water, the industry takes a major step forward in establishing sustainability as a technical and financially sound objective. ■
Stand 7222 (Hall 7)
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Helping to control energy efficiency MAGNETROL INTERNATIONAL HAS introduced the Heat Rate Reduction Kit, aimed at helping power companies manage controllable losses through effective, accurate feedwater heater level control. The Heat Rate www.magnetrol.com Reduction Kit is available for download at www.heatrate.magnetrol.com and addresses the mission-critical need to increase the efficiency of power plants in today’s challenging economic and regulatory environment. The Heat Rate Reduction Kit, an industry first, provides solutions that will help reduce fuel expenditures, which can account for 70 per cent to 80 per cent of production costs, by minimizing heat rate. According to Magnetrol, the potential savings represent an estimated US$676,000 annually for a 500MW power plant. “We created the Heat Rate Reduction Kit because we recognize the challenges power companies face today in an increasingly competitive environment and with the advent of climate change protocols and the Clean Air Act,” said Magnetrol's Product Manager, Jim Homoly.
Hydrasun’s regional expansion HYDRASUN, A SPECIALIST provider of integrated fluid transfer, power and control solutions to the global energy industry, has announced the launch of a new company and associated office and workshop facilities in the Middle East. Hydrasun FZE, based in Dubai, UAE, has been formed to support the company’s growing number of customers in the Middle East. The new 1,000 sqm facility will establish a permanent presence in the region supplying Hydrasun’s complete range of products and added value services as well as facilitating the pursuit of new business opportunities. Recent contract awards in the region include a contract for Instrument tubing and Hose Assemblies for the Barzan Project in Qatar, a long-term supply agreement worth approximately US$750,000 per annum with a leading oil services contractor in Dubai.
Stand 8251 (Hall 8) Added value services
Stand 11346 (Hall 11)
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Onshore, Offshore and Subsea
Technip takes it further At Technip in the Middle East, our specialized workforce of 1800 multinational staff is geared up to deliver ambitious energy infrastructure projects. Safety as a value, quality at the core of everything we do, entrepreneurial attitude, and anticipation are at the very heart of how we are taking it further.
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High definition imaging while drilling SCHLUMBERGER RECENTLY UNVEILED the MicroScope* HD high-definition imaging-while-drilling service, which the company claims provides unmatched logging-while-drilling (LWD) imaging for reservoir description to enable detailed fracture characterisation and completion Advanced technology optimisation in conductive drilling enables dip, fracture, and fluids for all well types, including texture answer products. horizontal and highly deviated wells. “In unconventional and carbonate reservoirs it is critical for geologists to fully understand the fracture networks that may challenge drilling operations and those that will contribute to production,” said Steve Kaufmann, president, Drilling & Measurements, Schlumberger. “This newly developed MicroScope HD technology provides detailed imaging of the formation to help prevent drilling risks, optimize completion design and potentially increase production.” According to a company
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statement, the MicroScope HD service enables detailed formation structural modeling to identify fracture orientation that contributes to production. An understanding of how formations are deposited is further enhanced with the service through sedimentology analysis. For fracture characterisation, the MicroScope HD service delivers dimensions of fractures, which provides geologists a better understanding of the fracture network. The MicroScope HD service has been field tested extensively in reservoirs in the Middle East, Europe and Africa, as well as unconventional reservoirs in North America. More than 45 job runs have been completed, confirming that highdefinition images can be obtained reliably in conductive mud environments while drilling in oil and gas carbonate, sandstone and unconventional reservoirs.
Stand 4320 (Hall 4)
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Integrated operations bring
benefits to region High-quality data and access to oilfield services has improved operational performance in an onshore workover and well testing project.
T
HREE RECENT INTEGRATED operations projects in the Middle East and North Africa illustrate the benefits of this operating philosophy to the region. Two of the projects took place in southern Iraq; the third, in ultra-deep water offshore India. An operator in southern Iraq wanted to evaluate formation properties and define field development programs for an onshore workover and well testing project in that regionâ&#x20AC;&#x2122;s Yamama formation. The project consisted of wells with downhole issues related to old completions and casing leaks. Five drilling rigs and three workover rigs were required to be mobilised within tight budgets and with penalties for nonperformance. In addition to high hydrogen sulfide (H2S) levels and 8,000 psi (55.2 MPa) formation pressures, the operator faced uncertainties related to casing and completion conditions. The area also had limited access to oilfield services along with heightened security and infrastructure concerns, and unreliable offset data made effective project planning especially difficult. Baker Hughes was brought in to assist with the project. After performing community development and environmental impact assessment studies through a thirdparty provider, critical safety and medevac procedures and H2S-control systems were established. Because downhole conditions in these wells were unknown, Baker Hughes experts developed multiple contingency plans and risk matrices for the project. Dedicated support teams in Basra and Dubai ensured clear communication channels and maximum operator interface. The operations team deployed certified high-pressure equipment with aligned testing procedures. While unforeseen downhole conditions presented a significant challenge, well data was flawlessly acquired and processed for accurate reservoir characterisation. Additionally, appropriate technologies were deployed to improve operational efficiency and save on overall 98
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Baker Hughes Integrated Operations provided a fast-track workover and completion solution for a seven-well project in Iraq, in which wells were completed 25 per cent faster on average than offset wells, with production in each increasing 300-400 per cent. costs. Altogether, Baker Hughes performed workover operations on three wells. Because there were no surface production facilities in place, all wells were plugged and abandoned using a kill string. Throughout the operation, the Baker Hughes engineering team adjusted programs, deploying additional services to wellsites to quickly respond to changes in downhole conditions and service requirements. Despite challenging downhole conditions and the lack of operational support in a remote region, the engineering team captured high-quality reservoir data and managed all Baker Hughes and third-party services efficiently and safely, eliminating down time. An operator working in southern Iraq needed to meet ambitious production targets on a seven-well workover and completion project to be eligible for
production sharing and cost recovery. Hampering efforts, the local infrastructure was extremely limited by a dearth of qualified service providers. Baker Hughes Integrated Operations proposed a fast-track workover and completion solution that included comprehensive well engineering, civil work, the provision of workover rigs and tubulars, and all additional services. This fully integrated solution included some local service providers who would supply demining services, security, water, and waste management. As a result, the operator was able to avoid having to negotiate multiple contracts with suppliers or hire additional manpower. Comprehensive project management and the effective management of third-party providers enabled spudding operations to begin within eight weeks.
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Activities included the successful removal of old completion strings, reperforating, stimulating, and running new completions in all seven wells. Wells were completed 25 per cent faster on average than offset wells, with production in each increasing to 3,000 or 4,000 bpd. Previously, these wells had been producing less than 1,000 bpd, and some had been completely unproductive. The operator was satisfied with the ability of Baker Hughes to provide a true turnkey service within a tight time frame. As a result, the contract has been extended twice, and further fast-track tenders are planned to build on these successes. All operations were conducted safely, with no lost-time incidents. After mobilising within a 45-day window, Baker Hughes continues to provide successful project management with all parties on a five-year ultra-deepwater development project offshore eastern India. The project encompasses air, marine, and shore base logistics as well as exploration and well construction services. Baker Hughes was selected to serve as the single point of contact to lead the integration of well services and logistics for
the development project, which is being undertaken in 10,000 ft (2,000 m) of water, using a new-build, dynamically positioned drillship. The goal from the beginning through completion of the five-year project is to leverage the expertise and experience of the integrated operations team to lead the project, pay close attention to detail, develop procedures, and maintain frequent communication among all parties. A dedicated Baker Hughes project team based in Mumbai provides project management support and coordinated key services and direct interface with the operator and drilling contractor for operations on a daily basis. The shore base, located in Kakinada, was built as a dedicated resource. The site includes a 16,000-barrel liquid mud plant, a bulking facility, casing and material storage, and a dedicated berthing facility for the support vessels. The Baker Hughes logistics manager provides the dedicated link to the operations team in Mumbai. Exploration and well construction services include directional drilling, logging while drilling (LWD), real-time data transmission, fluids, surface logging service (SLS), coring, liner hangers, cementing, and
casing handling. Third parties were contracted to handle wellheads, shore base support, and marine and air logistics (supply vessels and helicopters). Mobilisation for the project occurred quickly, with no schedule delays. The integrated operations team managed rapid deployment and build of facilities and mud plant and continues to coordinate movement of consumables for well construction. Experienced engineering, geoscience, and operations personnel support well design and operational execution. Additionally, Baker Hughes has provides a real-time operations center for their client. Among the continuing challenges of this project are to effectively manage the wide range of product lines and third-party companies and to maintain a close relationship with the operator in delivering services over the five-year project life, to maximise efficiency and performance throughout the planning and operational phases of the wells. Thus far, results have been excellent, and the project is progressing successfully. â&#x2013;
Stand 8210 (Hall 8)
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Jotun to showcase new mesh-free Passive Fire Protection (PFP) product at ADIPEC THE RISK OF jet fires from hydrocarbon on both offshore and onshore oil and gas facilities is never far from the thoughts of operators and safety experts within the oil and gas industry. Jotun hopes to quell these fears with the launch of its Jotachar JF750 mesh-free epoxy passive fire protection material, designed to provide protection to steel structures, divisions, vessels and safety critical equipment. Jotun has launched a mesh-free passive fire protection (PFP) coating designed to reduce installation time and material costs when installed on offshore and onshore facilities compared to epoxy PFP systems that require additional mesh reinforcement. According to Jotun Protective Coatings Middle East, India and Africa, Jotachar JF750 meets the requirements of local offshore operators who demand protection against jet fires for their offshore assets, ensuring compliance with stringent international offshore safety standards. A growing number of onshore refinery owners are now also demanding the benefits of jet fire capable PFP materials that can demonstrate jet fire capability to ISO 22899. Jotachar JF750 has undergone an extensive development and testing programme and is
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independently fire tested in accordance with all key industry standards for up to three hours fire protection. Andy Czainski, global PFP sales director for Jotun, describes the product as the "only mesh-free epoxy intumescent coating solution available to the market where jet fire protection is required for safety critical steel structures, divisions and vessels". "The formulation of Jotachar JF750 incorporates an advanced fibre matrix system in the material," says Czainski. "This technology, combined with a robust and temperature stable insulating char, eliminates the need for additional mesh reinforcement, reducing complexity and making it significantly faster to apply, saving both time and cost." Jotachar JF750 demonstrated what its manufacturer described as "exceptional jet fire performance in the ISO 22899 test" proving steel protection for up to two hours without the need for any additional mesh reinforcement and marking an industry first. The ISO 22899 standard has been developed to simulate the highly erosive, high-heat flux and rapid temperate rise experienced within a jet fire. Jotachar JF750 also passed a critical 4-bar blast overpressure test without any need of additional reinforcing mesh, proving a mesh-free system can withstand severe explosion
Extensive testing on Jotachar JF750 has seen it to meet an assortment of industry safety standards. (PHOTO: Jotun) and blast forces with no detachment. Key fire and blast resistance testing has been witnessed by Lloyds Register of London. The product is fully compliant to NORSOK M-501 revision 6, which is considered by many industry professionals to be the industryâ&#x20AC;&#x2122;s most rigorous durability and corrosion standard. "Major yards and specialist PFP applicators are telling us that the Jotachar JF750 mesh free system will be a game changer for them," says Czainski.
Stand 12166 (Hall 12)
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Schoeller-Bleckmann UK (SBUK) is a major stockholder in Duplex, Super Duplex, 6 Moly, Nickel Alloys and Stainless Tube, Pipe and other components. Via our parent company Bohler-Uddeholm (UK) Limited we have access to Wire, Rod, Round Bars, Plates and Forgings in the full range of corrosion resistant alloys. Our particular strengths lie in the supply of STAINLESS STEELS and EXOTIC GRADES Duplex (UNS S31803), Super Duplex (UNS S32760 / UNS S32750), 6 Moly (UNS S31254) and Nickel Alloys (625/825). Our Duplex materials are produced to high specification and are approved by BP / TOTAL / NORSOK / SHELL / ARAMCO / PDO etc. Our UK stockholding operation has ISO 9001, 14001 and 18001 accreditations.
Sales Office and Warehouse in Jebel Ali, Dubai Sales Office in Kuala Lumpur, Malaysia SCHOELLER-BLECKMANN UK EUROPEAN BUSINESS PARK, TAYLORS LANE OLDBURY, WEST MIDLANDS, B69 2BN Tel: +44 (0)121 552 1535 Fax: +44 (0) 121 627 9282 Email:richard.coates@schoeller-bleckmann.co.uk Web:www.schoeller-bleckmann.co.uk
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Bringing our piping solutions a step closer Piping materials from stock: f_f[i" jkX[i" Ñ jj_d]i WdZ Ò Wd][i _d ijW_db[ii ij[[b" Zkfb[n" ikf[hZkfb[n WdZ if[Y_Wb Wbbeoi
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BAPCO invests in environmental
projects BAPCO is at the forefront of Bahrainâ&#x20AC;&#x2122;s green drive and has implemented several environmental projects.
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S AN INDUSTRY leader, BAPCO has taken upon itself the responsibility of pushing through numerous initiatives that have helped in not only increasing overall environmental awareness, but also demonstrated that sustained progress is achievable without damaging the environment. The company has embarked upon implementation and execution of the following environmental projects:
Wastewater Treatment Plant Project
As part of its commitment to the protection of the environment BAPCO embarked on constructing a new Waste Water Treatment Plant (WWTP) at a total value of US$120mn to treat its refinery oily wastewater.
The refinery currently uses primary treatment to remove solids, oil and grease from oily waste water. The new WWTP provides secondary treatment by utilising Membrane Bioreactor (MBR) to treat dissolved organics, as well as nitrogen and spent caustic.
The joint objective is to convert a waste stream into a valuable product With this new plant, compliance with stringent environmental regulations stipulated by the government of Bahrain for wastewater discharge into the Gulf will be achieved.
It will be the first MBR application of its scale, i.e. 4,400 US gallons per minute (gpm) to treat refinery waste water and will be benchmark for other refineries within the region and around the world. Also, an innovative technology for treating the most toxic spent caustic within the biological section was developed inhouse, which will provide rich benefits in treating the toxic spent caustic as well as to utilise its capability as a rich source of food for the biomass and as an alkalinity provider for the biological treatment. Additionally, the project implemented construction of new concrete Emergency Pond to replace the earlier Skim Pond. The old Skim Pond was of earthen construction and was not environment friendly. Furthermore, to enhance Bapcoâ&#x20AC;&#x2122;s image as environmentally responsible company, the Issue 7 2013
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project implemented Bahrain’s longest landscaping covering a span of two kilometres near Maameer Village at a total value of US$2.2mn. This landscape also screens BAPCO facilities from nearby residential areas thereby avoiding unnecessary exposure of its assets to public. The project is now mechanically complete. Currently pre-commissioning and commissioning activities are progressing. Treated effluent quality meeting GDEWP specifications will be achieved by Q4 2013 after completion of plant commissioning.
conventional methods that entail burning of fossil fuels. The plant will initially have a capacity to capture and recover 200 metric tons of carbon dioxide per day. That figure can be doubled in the near future.
CO2 Project
The construction work for the CO2 Recovery Plant is complete and is in the precommissioning phase. The construction phase was complete with minimum disruption to the regular operations of the refinery. The plant, split into on-site facilities (inside BAPCO Refinery battery limits) and off-site facilities (built on BAPCO leased land outside the refinery fence), is expected to be commissioned by 2014. BAPCO and Yateem Oxygen, a longestablished and reputable local company involved in the industrial gases business,
The Carbon Dioxide (CO2) Recovery Plant Project is an ambitious environment conservation project that BAPCO and Yateem Oxygen are embarking on in close co-operation and partnership for a cleaner and greener Bahrain. The joint objective is to convert a waste stream into a valuable product and reduce consumption of fossil fuels, thereby delivering economic and environmental benefits. This is for the first time in Bahrain that carbon dioxide will be extracted in an environmentally safe manner as against
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The refinery currently uses primary treatment to remove solids
signed a renewable 15-year technical and commercial agreement for a Carbon Dioxide (CO2) Recovery Plant near the BAPCO Refinery in May 2011. The CO2 Recovery Plant will be built, owned and operated by Yateem Oxygen while BAPCO will provide a carbon dioxide rich feed stream from the refinery’s No.1 Hydrogen Plant which is currently vented to atmosphere. This is the first time in Bahrain that carbon dioxide will be extracted in an environmentally safe manner as against conventional methods that entail burning of fossil fuels. The plant will initially have a capacity to capture and recover 200 MT of carbon.
Bahrain Distributed Solar Energy Pilot Project (BDSEPP) Bahrain is one of GCC countries that sees more than oil in the region’s future. Bahrain is blessed with an abundance of another natural resource: sunshine. It has expressed a strong desire to support renewable energy and improve energy efficiency as a mean to conserve valuable natural resources. To support these initiatives, BAPCO
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sponsored a pilot project for the deployment of solar power units primarily in Awali, Refinery and University of Bahrain. The project is a collaborative effort between the National Oil and Gas Authority (NOGA) and the Bahrain Petroleum Company (BAPCO), in co-operation with the Electricity & Water Authority (EWA), and the University of Bahrain. This initiative demonstrates Bahrain’s commitment to addressing the challenges of energy security, climate change, and economic development through global partnerships and collaboration. Bahrain is the first in the Gulf to implement a project of this kind that combines solar technology with smart grid solutions, demonstrating a serious commitment to long-term economic solutions. Currently, the economic development of the Kingdom relies primarily on the availability of reliable and competitively priced energy. The Kingdom’s ability to maintain a reliable, sustainably priced energy is challenged by a steadily increasing electricity demand at a time when the indigenous energy resources of Bahrain are declining. The price of energy has increased substantially in the past few years with expectations are that this upward trend will continue. The price of natural gas in Bahrain has gradually increased from US$1.100/MMBtu in 2008 to US$1.5/MMBtu in 2011. The price of natural gas was increased to US$2.25/MMBtu in January 2011. If not mitigated, the unsustainable combination of increasing natural gas consumption and increasing prices will invariably strain the Kingdom’s economy. Power generation is the largest consumer of natural gas accounting for 33 per cent of the demand. The use of natural gas for electricity generation represents a significant opportunity cost to Bahrain which generated 266.3 bcf. in the first half of 2010, a 3.5 per cent year on year increase. Gas used for domestic electricity generation presents an inefficient utilisation of a valuable resource. Factoring in government subsidies for electricity, the opportunity cost of using natural gas for domestic energy production is glaringly evident. A form of contract on a five megawatt distributed smart solar energy pilot project that will provide solar energy and increased efficiency through the use of smart grid technology to the BAPCO township of Awali, Refinery Car Parking areas and the University of Bahrain was signed on 20th June 2012 by BAPCO and Petra Solar on an EPC basis. The project will use smart solar
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BAPCO sponsored a pilot project for the deployment of five solar power units primarily in Awali, Refinery and University of Bahrain
technology which couples solar energy generation with grid reliability and smart grid technology. The technology was developed in the US by Petra Solar, a technology company focused on providing reliable, costeffective smart energy solutions to the electric supply industry. The initiative will create jobs at several skill levels in Bahrain and will also provide a strong research and development opportunity for Bahraini universities.
STG Project
The replacement of the steam turbine generators (STG Project) has contributed to reduced environmental emissions from the refinery. The STG project, completed at a cost of US$108mn in December 2012, included the installation of two (2) 14 MW steam turbine generators to replace the five existing turbine generator which have been retired after being in service for over 40 years.
The joint objective is to convert a waste stream into a valuable product STG’s contribution to the environment is through improved efficiency of the conversion of high-pressure steam into power generation at the refinery, compared to the redundant turbine generators and less reliance on the less efficient gas turbine generators, and thus a reduction (albeit slight) in greenhouse gases emitted to the atmosphere from the refinery. In other words, less reliance on the gas
turbines means less fuel burnt and hence less environmental impact; the contribution is relatively small but is a contribution nonetheless.
Conclusion
In its pursuit of excellence in environmental performance and to reinforce its commitment to a clean and green Bahrain under the slogan ‘We Care’. BAPCO will lead Bahrain’s green drive in the future as well even as it develops and executes the largest ever project in BAPCO’s and Bahrain’s history: the BAPCO Modernisation Programme. One of the key objectives of this modernisation programme is full and complete environmental compliance. Although BAPCO has launched and completed several ‘green’ projects and has come a long way in meeting environmental regulations, BAPCO believes that there are always areas of improvement and challenges to be addressed. One such challenge will be BAPCO’s FCC Unit’s current levels of particulate emissions and all efforts will be made under the BAPCO Modernisation Programme to resolve the issue permanently, to highlight that ‘We Care’. Also, all other similar issues shall be identified under BAPCO’s Modernisation Programme and steps shall be taken to ensure full compliance. BAPCO’s commitment to the preservation of the environment for its future generations is firm and unshakeable. BAPCO would like to prove that conserving nature is not a drag on growth; BAPCO shall walk the extra mile for its protection as it believes that it is an unavoidable prerequisite for sustaining the economic development of Bahrain and its future. ■
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Rising to the
challenge ADNOC is ready for the oil and gas production challenge despite concessions delay.
A
BU DHABI’S DYNAMIC oil and gas sector - by far the largest in the UAE - continues to thrive.
At it’s heart is the state-owned oil firm, Abu Dhabi National Oil Company (ADNOC), which has a stake in almost all corners of the industry, both upstream and downstream, via it’s multiple subsidiaries. In the field, oil production is riding high and expected to grow further in the years to come, with investment soaring. This September, the UAE produced some 2.7mn to 2.8mn barrels per day (bpd) in total, with Abu Dhabi accounting for more than 90 per cent. The UAE combined holds the seventhlargest proved reserves of crude oil in the world at 97.8bn barrels.
Central role
Again, the majority of these reserves are located in Abu Dhabi, approximately 94 per cent. And there is every intention of exploiting this resource potential to the max with
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ADNOC planning to lift production capacity up to 3.5mn bpd by 2017. It gives Abu Dhabi a very prominent position in the Gulf - high spending on energy sector projects in recent years has attracted huge industry interest - as well as within the Organisation of Petroleum Exporting Countries (OPEC).
And things are not likely to cool down for some time yet, with more ADNOC supported projects lined up across the board Abu Dhabi’s big production hike is expected to come from a range of new and existing oilfields, both onshore and offshore. Once again, ADNOC companies will play a central role in making this happen, in conjunction with foreign partners.
The Shah Gas project could be up and running by the end of next year
Offshore, Abu Dhabi Marine Operating Company (Adma-Opco), is working to lift its output to one million bpd by 2020, up from around 600,000 bpd currently. One of its flagship projects is the Umm Lulu field development.
Next phase
This year, it handed a US$1.6bn contract to a consortium of France’s Technip and local firm National Petroleum Construction Company (NPCC) to develop the field. Adma-Opco groups ADNOC with BP, Total and Japan Oil Development Company (JODCO). Also offshore, Zakum Development Company (ZADCO) - which groups ADNOC with ExxonMobil and JODCO - is looking to raise production capacity to 750,000 bpd by 2015. Earlier this year, Petrofac Emirates shared a US$3.7bn contract with Daewoo Shipbuilding & Marine Engineering Co. Limited (DSME) to lead the Upper Zakum UZ750 field development. The work entails installing various oil production and processing infrastructure on
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four artificial islands in the Gulf. All of these projects are huge in scale and will underpin the next phase of Abu Dhabi’s economic growth.
Concessions
More immediately, however, is maintaining steady oil flow from onshore and shallow coastal fields through the Abu Dhabi for Onshore Oil Operations (ADCO) concession. This joint venture accounts for more than half of the UAE’s entire output, producing mainly from six oilfields: Asab; Sahil; Shah; Bab; Buhasa; and North-East Bab (Dabbiya, Rumaitha and Shanayel). ADNOC holds a 60 per cent controlling stake in ADCO, while oil giants ExxonMobil, Royal Dutch Shell, Total and BP, each hold 9.5 per cent stakes. Delays in the oil concession renewal process could potentially impact ADCO’s operations, though officials insist this will not happen. The current licences - now four decades old - expire at the start of 2014. International firms are keen to stay in the concessions, which allow them to hold equity stakes in upstream oil fields, a rare opportunity in the conservative Gulf region, and unlike the nationalised oil industries of Saudi Arabia and Kuwait.
Pressure
There is a belief that delays to the concession renewal process, and the complexity of it, could threaten Abu Dhabi’s 2017 production targets. After receiving the new bids - to run the ADCO concession for decades to come officials still need several months to study the offers and submit recommendations to the Supreme Petroleum Council (SPC). All of the existing ADCO partners are keen to remain involved, though new investors, particularly large state oil concerns from Asia, are also thought to be interested in taking a slice of the action. Potentially, the new-look ADCO concessions may thrive once the new arrangements are finalised, with the injection of new investment and technology. At the same time, ADNOC is leading Abu Dhabi’s efforts to monetise its vast gas reserves. Although the emirate has long been an exporter of liquefied natural gas (LNG), via the Abu Dhabi Gas Liquefaction Company (ADGAS) facility, high economic growth rates and demand have put pressure on local supplies.
The massive boost underlines the extent of Abu Dhabi’s broad energy sector investment here is unlocking the complex sour gas deposits offshore, which are more technically challenging than conventional fields; the gas contains a high percentage of hazardous hydrogen sulphide which needs to be dealt with. And that’s a costly business. The US$10bn Shah sour gas project, which pairs ADNOC with Occidental Petroleum of the US, will pump some one billion cubic feet per day of high sulphur gas, but only actually deliver about 500mn cfd of network gas after removing the sulphur content. The project could be up and running and delivering first gas by the end of next year. A similar volume of network gas will be produced from the ultra sour Bab gas project, in which ADNOC teams up with Shell.
More abundant
This development, which will produce 520mn cfd of network gas after stripping it from impurities, is expected to follow by 2020. Despite their cost and complexity, these projects have been sanctioned to feed rising demand from the power sector and industry; a lot of gas is also used to be re-injected into the nation’s oil fields to maintain oil pressure. But a more abundant gas supply would also free up more of Abu Dhabi’s oil for export, and further diversify the economy away from oil.
The truth is that with cheaper gas now harder to come by it means Abu Dhabi must now rely on these more challenging fields to obtain the resources it needs. And there is likely to be a heightened role for gas imports too in the coming years. An LNG terminal is also being built in the emirate of Fujairah to feed local gas demand, in addition to Dubai’s offshore import facility. The new terminal will import some nine million tons of LNG a year. In 2013, UAE gas sales are estimated at about 5.2 bcfd, according to Wood Mackenzie estimates. Out of this, about 57 per cent are domestic sales and LNG exports, with 37 per cent from Dolphin imports via Qatar, and six per cent from LNG imports.
Regional leader
One of the underlying issues, of course and something where there is no quick fix is the UAE’s high energy subsidies, a common theme throughout the Gulf. This has the dual effect of encouraging domestic consumption and yet undermining the commerciality of gas supply. However, at least a part of the solution rests outside the oil and gas sector. Like a number of other Gulf states, the UAE is actively looking to exploit other energy alternatives, including nuclear power. Four nuclear reactors, now being developed by a South Korean consortium led by Korea Electric Power Corporation, could be up and running by 2020. Long-term, this could account for up to a quarter of the UAE’s electricity generation. Abu Dhabi has also emerged as a regional leader in the renewable energy segment.
Costly business
Abu Dhabi is now importing pipeline gas from Qatar, while neighbouring Dubai is buying in its own LNG from overseas. One of the problems engineers face
www.adco.ae
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Expansion of the Ruwais facility is nearing completion
It was named host city for the newlyformed International Renewable Energy Agency back in 2009. ADNOC companies are also leading Abu Dhabi’s downstream development too. In the refining sector, the Abu Dhabi Oil Refining Company (TAKREER) runs the Ruwais and Abu Dhabi refineries. It is nearing completion of the US$10bn Ruwais expansion, which is focused on meeting the product needs of the local market. The expansion will effectively double capacity at Takreer’s two refineries from about 490,000 bpd to nearly one million bpd. Borouge, a joint venture of ADNOC and Austria’s Borealis, is a large plastics and petrochemicals producer.
Massive boost
In 2010, it tripled its annual production capacity in Abu Dhabi to two million tons. Borouge is currently expanding the annual capacity of its plastics manufacturing plant in Abu Dhabi once again from two to
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4.5mn tons per year to meet the growing demands of the infrastructure, automotive and advanced packaging markets in the Middle East and Asia. This will create the world’s largest integrated polyolefins plant. There are also plans to upgrade supply and logistics support to handle the increased capacity, based on the need to ship up to 1,100 containers every week from Borouge’s Abu Dhabi production plant. Another ADNOC unit, Fertil - which groups the state oil concern with Total - also boosted its total capacity this year, launching first urea production from the Fertil-2 project. This upgrade also effectively doubles previous production.
ADNOC is planning to lift production capacity up to 3.5mn bpd by 2017
The massive boost underlines the extent of Abu Dhabi’s broad energy sector investment. And things are not likely to cool down for some time yet, with more ADNOC supported projects lined up across the board.
High growth
The heavy spending of recent times - and the award of numerous multi billion dollar contracts - has excited international engineering firms and contractors. As well as racing to supply its own needs, Abu Dhabi is also responding to the changing global energy market, focusing more of its attention on the high growth Asia markets. The ADGAS LNG facility has long supplied Japan, but it seems likely that Abu Dhabi’s future could well be ever more closely linked with the more dynamic economies of Asia. This is certainly the rationale behind getting Asian oil firms engaged in the newlook ADCO concessions. With the ADCO concessions capable of producing some 1.6mn bpd this is a key moment for Abu Dhabi, and indeed ADNOC itself, at the heart of the emirate’s oil and gas sector. How these concessions look next year could give a vital glimpse into how Abu Dhabi’s energy sector of the future might take shape. Until then, and during this period of uncertainty and heightened demand, ADNOC and its operating divisions will be charged with keeping the ship steady - continuing to produce the oil, boost capacity, and further diversify the nation’s energy wealth. Based on past performance there’s every reason to think that Abu Dhabi’s oil and gas riches remain in safe hands. ■
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Mott helps maintain efficiency MOTT MACDONALD HAS its main office in Abu Dhabi and is involved in a number of key projects in the city and the wider region. The consultancy’s knowledge and expertise is being utilised to maintain operational efficiency and increase production across both onshore and offshore oil and gas fields. “Abu Dhabi is in the middle of a five-year, US$40bn plan aimed at boosting oil and natural gas output and expanding petrochemical and refining facilities. The aim is to increase crude oil production capacity from 2.7mn bpd to 3.5mn bpd by 2017,” said Hisham Alami, Mott MacDonald’s general manager for oil, gas and petrochemicals Hisham Alami in Abu Dhabi. Onshore, Mott MacDonald is currently working as project management consultant (PMC) for two major CO2 enhanced oil recovery (EOR) projects by ADCO. These projects pertain to Rumaitha CO2 Conversion and BAB Far North CO2 Pilot Project in connection with NEB Phase-III development. Mott MacDonald is already working on NEB PhaseIII development project as PMC on the on-going field development projects. On the offshore side Mott MacDonald was recently awarded a FEED project for the upgrade of the power generation system at
Umm Al-Dalkh oil field by Zakum Development Company (ZADCO). Within the wider scope of the UZ750, ZADCO’s plan to increase oil production from the Upper Zakum field initially to 750,000 BOPD and to sustain it for 25 years, our office in Abu Dhabi will be providing detailed engineering for the process, utility project AUP and accommodation. The project, awarded by the EPC contractor Habtoor Leighton Group Company, consists in providing accommodation and utilities on the four artificial islands being constructed by ZADCO to increase oil production. Mott MacDonald has a well-established presence in the Middle East dating back to the 1960’s. The consultancy employs over 15,000 staff and has more than 170 principal offices in 50 countries, enabling it to meet the needs of multinational and multi-sector clients worldwide. Its oil, gas and petrochemicals team is made of more than 1400 staff including world experts in their fields. Among its award winning projects in the UAE are the water injection upgrade in the Lower Zakum field for ADMA-OPCO and the Gulf Petrochem storage terminal in Fujairah.
Stand 8151 (Hall 8)
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Ducab adds value to relationship with ADCC DUBAI CABLE COMPANY (Ducab), one of the largest manufacturers of power cables and copper products in the region, held a week long technical training for the first batch of 22, ADDC Technicians and Engineers in the factory premises in Abu Dhabi and Jebel Ali. The training session was followed by a ceremony to award the Technical training underway Certificate of Proficiency to the candidates to acknowledge their great success in learning the basics of cable systems, including demonstration of cable jointing and terminations during installation and maintenance. that their strategic partnership with the Abu Dhabi Distribution Company (ADDC) has been over the last year. The ceremony was attended by senior management figures from both companies. ADDC relies heavily on its high performance and wide spread cable systems networks to provide 24x7 power flow across Abu Dhabi region.
Stand 6322 (Hall 6)
A new reporting solution from Promineo PROMINEO AS, A leading project software provider for the oil and gas sector in Norway, is launching its newest solution, S-Curves for Primavera, at ADIPEC. The product extracts data from Primavera P6 to enable reports that Primavera P6 lacks, and it brings further reporting flexibility for project management. By removing the need to resort to Excel in reporting, the software also helps to minimize human error. Built on Promineo’s robust data mining platform Proteus, S-Curves for Primavera is designed to keep the true history data of a project intact. This makes it possible to maintain accurate baseline data throughout a project and to enable re-baselining a project without any loss of visibility. More than this, the software comes with powerful forecasting functionality, and it is broadly customizable depending on the needs of a given www.promineo.no/ project, including the option to report all project variables as a percentage of completion. When talking to Leif Arild Aasheim, the managing director of Promineo, you can clearly sense his excitement regarding the launch. “S-Curves for Primavera was developed in close collaboration with a large oil and gas contractor, based on a clearly expressed need, and therefore we know the solution S-Curves for Primavera provides is in demand, and what is more, it has clear value to the customer. I am truly looking forward to introducing the software to the market” says Aasheim. “Due to the large number of EPC contractors operating in the Middle East, and the prevalence of Oracle Primavera P6 in the region, ADIPEC is the natural choice for the launch of S-Curves for Primavera.”
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Maersk Oil signs agreement with Gulf Drilling MAERSK OIL QATAR (MOQ) and Gulf Drilling International (GDI) have signed two new contracts; one two-year contract for the GDI jack-up drilling rig (rig ‘B-341’), and another three-year contract for a new GDI offshore accommodation jack-up. The total value of these contracts is more than US$205mn. The October signings represent the second and third major agreements between GDI and MOQ in 2013. In February this year, the companies signed a contract for the offshore jack-up drilling rig “Al Jassra”, which is already working in the Al Shaheen field. This makes the total agreements signed between MOQ and GDI in 2013 worth a combined amount of about US$428.5mn. The agreements were signed by MOQ’s Managing Director Mr. Lewis Affleck, and GDI’s Chief Executive Officer, Mr. Ibrahim J. Al-Othman. Also in attendance were: Mr Saad Sherida Al Kaabi, Director of Oil and Gas Ventures of Qatar Petroleum; Mr Jakob Thomasen, Chief Executive Officer of Maersk Oil; and Sheikh Faisal Bin Fahad Al Thani, Deputy Managing Director of MOQ.
Stand 7122 (Hall 8)
Learn with Bulwark AT BULWARK, THEY don’t just strive to be the world’s leading provider of fire resistant (FR) apparel, they also aim to be the industry’s pre-eminent FR educator, resource and business partner. With Bulwark University, the company has distilled 42 years of on-the-job training into a series of training courses to help make you safer. And more successful. Bulwark’s training courses/seminars can be experienced at ADIPEC this year, on 11th November (1400-1530), 12th November (11.00-1230) and 13th November (11.00-1230). Entitled, Understanding NFPA 2112/2113 and the Flash Fire Hazard, attendees will learn about the primary subjects essential to understanding, and protecting against, the flash fire hazard in the workplace. Causes and consequences of flash fire are examined, with emphasis on historical data, real accidents, body burn injury and non-flame resistant vs flame resistant clothing. This section includes video clips of flash fire on clothed mannequins in typical working positions. Discussion will take place concerning the current standards and enforcement and how they can be globally applied by implementing best practices. The seminar will cover the test methods and standards related to performance of proven flame-resistant garments available today. This session will utilise
http://www.adipec.com/page.cfm/Action=Form/FormID=41/t=m video and photographs to demonstrate the difference between non- FR and FR work clothing as it relates to the hazard of flash fire. Attendees will take away: The latest in flame-resistant fabrics Understand the technical terms surrounding the flame-resistant clothing market Difference between flame-resistant clothing and every day workwear. Questions to ask when developing a flame-resistant program at your facility
Stand HSE13 (Hall 1) Issue 7 2013
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Raccortubi eyes regional growth AS A NEW company in the Middle East, in terms of the nature of the material itself, Raccortubi is only just starting out. However, but also as far as the quality of the end the company is pleased with the potential product is concerned. All butt weld fittings in that it sees in the regional market. duplex, superduplex and 6Mo that emerge "We have identified a strong niche market for from our Tecninox facility have been ourselves: piping components in special rigorously analysed in accordance with the materials, for example duplex, superduplex, group’s internal specifications, superaustenitics and nickel alloys. encompassing those of NORSOK M-650 Ed. Furthermore, what makes us stand out is our 4, to ensure that chemical compositions, dual status as both stockist and mechanical values and supplementary manufacturer. Raccortubi Middle East’s testing meet and exceed quality stock of butt weld fittings will be supplied requirements. This means Raccortubi is able directly by the Group’s very own Tecninox to provide ex-stock materials which already manufacturing plant, enabling us to offer adhere to the most stringent market consistently short delivery times. In addition, demands. What’s more, the client is able to we have strong long-term purchase order the required materials and download A view of Raccortubi’s regional office contracts with our suppliers, who are the accompanying quality certifications from amongst the world’s leading manufacturers," said Sunzeev Swami, managing Raccortubi’s website even before the products are collected or shipped. director, Raccortubi Middle East FZE. “Since ADIPEC 2013 will be Raccortubi Middle East FZE’s first outing on the He continued, “In particular, we observe a heightened demand for piping exhibition stage, we will be focusing on promoting our expertise. We look components in materials such as stainless steel, duplex, superduplex, forward to meeting both new and existing Raccortubi customers, and laying superaustenitics, urea grades and nickel alloys. Project requirements are the foundations for strong long-term relationships. We want to make clients becoming ever-more demanding and the need to provide a wide range of aware that we supply products of proven quality and that we benefit from the critical piping components in special materials is increasing. We can supply relevant certification and approvals, as well as being included on a large products in all these specific grades, from stock and from our production.” number of vendor lists,” concluded Swami. The company sees huge potential in the provision of pipes, tubes, fittings and Stand 1432 (Hall 1) flanges in stainless steel, duplex, superduplex, urea grades and 6Mo, not only
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Well flow management expertise from Expro EXPRO’S MISSION IS well flow management. The company provide services and products that it claims measure, improve, control and process flow from highvalue oil and gas wells, from exploration and appraisal through to mature field production www.exprogroup.com optimisation and enhancement. Expro’s vision is to be the market leader • Drilling & Completion in well flow management, using the • Flowback and Clean-up industry’s best people, to deliver the highest • Production standards of safety, quality and personalised • Well Integrity & Intervention customer service. Expro has a strong presence in the Expro’s 40 years of experience and Middle East and North Africa region, with innovative technology empowers the extensive operations in Saudi Arabia, Iraq, company to offer tailor-made solutions for its Oman, Algeria, Egypt and Libya. customers across the energy sector. With The company provides a range of 5,000 employees across 50 countries, Expro solutions across six areas of capability: says it offers a truly global service solution. • Exploration & Appraisal Testing Stand 9235 (Hall 9) • Subsea Safety Systems
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Energy efficient solutions A GLOBAL MAJOR in the power distribution, automation and control sectors, WEG celebrated its 50th birthday in 2011. The company’s global sales now exceed the US$3bn mark, representing increasing global success across a wide range of product groups, including the latest generation of transformers, LV control gear, generators, gear motors, inverter drive systems, soft starters, LV and HV motors, ATEX- compliant explosion proof motors, smoke extraction motors and full turnkey systems. In addition, WEG recently made a significant strategic expansion of its product portfolio, following the establishment of a joint venture for the manufacturing of wind turbines and the purchase of an Austrian gearbox manufacturer, WATT Drive. WEG has grown into a global solutions provider of electric-electronic technologies and equipment. WEG is now one of the largest manufacturers of electric motors in the world.
Stand 12210 (Hall 12)
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Seco rolls out cutting tool solutions THROUGHOUT THIS YEAR, Seco has released a Turbo helical comprehensive range of new cutting tool application solutions for milling, turning, threading and holemaking operations – all designed to assist manufacturers across all industry segments in optimising their machining processes by boosting their productivity and profitability. For milling operations, Seco has introduced an innovative 335.25 disc milling cutter with an adjustable cutting width. Seco says this product offers exceptional performance in all demanding disc milling applications where productivity and versatility are required. The new Turbo helical cutters are available in diameters from 32 mm to 80 mm with cutting depths between 0.8xD and 2.0xD and include Seco-Capto ™ mounting options. The broad range of advanced Turbo inserts, which includes new grades and geometries, for these helical cutters bring increased metal removal performance to materials with unique machining challenges, including titanium, aluminium and stainless steels. A Seco statement added that the high level of versatility that comes with this range of helical cutters allows manufacturers to optimise existing applications, whether they have rigid or weak machining conditions. In terms of its premium line of Jabro solid carbide tools, Seco will introduce the JHP951 solid end mill for roughing applications. The new cutter apparently offers 30 per cent higher material removal rates when compared to the existing JHP950. The JHP993 solid end mill with roughing profile for complex roughing applications where the workpiece is not completely solid or difficult to clamp.
Stand 216 (Hall 2)
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A world first PRESSURE MANAGEMENT SPECIALIST Elfab will be demonstrating its new Ex dapproved burst detection system, FloTel™ XD, and forward-acting rupture disc, SafeGard, at ADIPEC 2013. Flo-Tel™ XD offers one of the most costeffective burst detection systems available for key applications, such as LNG. Fully Ex dapproved, the new product reduces installation costs by removing the need for intrinsically safe barriers and interfacing directly with the remote terminal unit. Elfab says Safe-Gard is the world’s first three per cent tolerance forward-acting rupture disc and is particularly useful for high-pressure applications, where customers are seeking to maximise the throughput of their process. It comes ready for use with Flo-Tel™, Elfab’s non-invasive detection system. The company will also be showing a range of products and videos at ADIPEC, focusing particularly on the premium OptiGard™ rupture disc range. Key members of Elfab’s board of directors will be present at the company’s stand.
Stand 10370 (Hall 10)
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New regional office and new technology for SICA BURNER MANUFACTURER, SICA, is celebrating its 50th year in business this year by investing in new technology and opening a new office in Dubai, UAE. SICA, which has also implemented new organisational and production strategies, has opened the new regional office to improve the company's service to its customers. Headquartered in Legnago (Verona) in Italy, SICA manufactures burners and burner components for the industrial, petrochemical, residential and marine sectors. The company has recently invested in new technology, such as robotised welding lines and a laser-cut machine. These have been added to the company's existing advanced technology systems to achieve greater precision and maximise quality and the overall processing speed. The whole welding process is certified UNI EN 287 and ASME IX. SICA's commitment to improving its product development process also includes implementing changes to the company's internal organisation. SICA are implementing a lean manufacturing approach to its fabrication and managing systems to minimise waste and enable more cost-effective and flexible production.
SICA robot weld
Stand 12070 (Hall 12)
Sulzer Pumps continues regional push SULZER PUMPS DESIGNS, develops and supplies pumping solutions and related equipment worldwide. The company's intensive research and development in fluid dynamics, process-oriented products, and special materials as well as reliable service solutions help Sulzer Pumps maintain its leading position in its key markets. Its customers come from the oil and gas, hydrocarbon processing, power generation, pulp and paper, water and wastewater sectors, as well as from specialised areas in the general industry. The company has a network of 22 manufacturing facilities worldwide and sales offices and service centres in 170 locations globally. A global leader in its selected markets, Sulzer Pumps employs around 8,500 people worldwide. The company is known for providing high quality, technologically advanced pumping solutions.
Its wealth of experience and team of expert engineers means Sulzer Pumps can devise and produce engineering solutions for the fast-changing demands of the industry. The company's success in the oil and gas industry is based on its ability to break through technological barriers and provide reliable equipment. Sulzer Pumps works with its customers from concept phase through design, manufacture, testing, installation, operation and services. Sulzer Pumps produced the first 27MW water injection pump and delivered the world's highest pressure water injection pump (605 bar discharge pressure), the world's largest multiphase pumps and liquefied natural gas (LNG) send-out pumps, and helped to develop the world's highest power subsea pump. Reliable water injection is critical to modern oil production processes and relies on efficient, reliable pumps that can operate
Sulzer Pumps also supplies pumps for installation on FPSOs
for extended periods before needing maintenance. Sulzer Pumps' range of pumps specifically tailored for injection applications reduces cost and lead times for its customers.The company offers a broad range of multistage pump types (BB3 and BB5) for water injection, direct drive and high speed solutions for high pressure service. Sulzer Pumps is a leader in this field of technology, with a wealth of experience and references above 2000-3000 m of head. The company is responsible for the world's largest and highest pressure sea water injection pumps. Re-injecting produced water is an extremely abrasive application and the detrimental effect on a pump's performance will be evident sometimes within weeks of an extreme application. Together with Sulzer Metco, another division within Sulzer, the company has developed coating technology designed to greatly extend pump life (approximately 18 to 24 months compared to six to eight weeks for unprotected pumps). Sulzer Pumps has been awarded a number of large water injection projects in Kuwait, Oman and Iraq in recent years. The company's awareness of the oil and gas industry's renewed emphasis on improving safety standards is driving Sulzer Pump's continuous improvement of work processes, designs and the reliability of the equipment used in these projects. Safety is a top priority at Sulzer Pumps, from the safety of its own employees to the safe operation of the equipment the company provides to its customers. Sulzer Pumps' focus on this particular area can also enable its customers to achieve higher levels of safety performance in their projects.
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Volatile oil market
shows change The September reports of OPEC and the IEA reviewed the latest thinking on shortterm supply and demand. We look further ahead.
Saudi Arabia can be relied upon to maintain supplies
C
RUDE OIL PRICES continue to hover above the US$100 level for benchmark WTI, representing a fall on last month’s level but well ahead of October 2012. All parties agree that the key determinants over the last month have been the unexpected political developments in weapons decommissioning in Syria, which have weakened the market, and the continuing difficulties with shut-in output and other problems in Libya, which have had the opposite effect. “Heating up and cooling down” is how the International Energy Agency described the situation succinctly in the middle of September.
Consumption
Over the longer term the market is still digesting the likely impact of future selfsufficiency in overall energy supplies, and possibly in crude oil too, in the USA. In 2012 this country was again the world’s biggest importer of both crude and products; in that year consumption dropped by 2.3 per cent at the same time as US domestic output registered its biggest increase ever. As the representative of the principal producers’ group OPEC points out (in its September MOMR) that its own Reference Basket averaged US$107.52/b in August, an increase of just over US$3 on the previous month. However year on year the basket price was down, and that was before the breakthrough Russian move in Syria; futures went up healthily nevertheless. From Vienna the Organization pointed out at the same time that world economic growth forecasts for both this year and next remain unchanged, including conditions in China which continues to play the role of “leader of the pack” (and number two in terms of oil imports too). In October, the IMF agreed. 126
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Mainstay
‘Overall, developed economies are recovering – albeit from low levels’ the OPEC monthly report says, ‘amid a slowdown in emerging and developing economies.’ In previous years it has been the latter group that have consistently been the mainstay of growing demand for oil. To sum up OPEC’s views on the current market the latest Monthly Report says world demand for oil is expected to grow by 1.0 mbpd in 2014, following the emergence of higher than expected actual data from the first half of 2013. The bottom line is that demand for the group’s crude this year is expected to average only 29.9 mbpd, which represents a
A regional and possibly global glut of gas seems to be on its way.
drop of 0.5 mbpd on last year. ‘Demand for OPEC crude in 2014 was revised down slightly to 29.6 mbpd since the last MOMR to show a decline of 0.3 mbpd compared to the current year.’ From the other (i.e. the consuming and mostly buying-in) side of the counter the IEA’s own September OMR emphasised the escalation of oil futures through August, followed by a swift turndown early in September as the (already faltering) US plan for Syria was surprisingly outsmarted. The continuing Brent premium over WTI stood at just over US$4.00 in the middle of that month. Global demand growth ‘remains flat at 895 kb/d for 2013’, the Agency says, throwing in the extra concern that the effect of currency fluctuations in emerging market economies (notably India but reaching well beyond Southeast Asia to Brazil too) is likely to have an impact on the market soon.
Saudi output
However, “Demand growth is forecast to rise to 1.1 mbpd in 2014 as the underlying macroeconomic backdrop solidifies”;
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developing Asia’s, especially India’s, current troubles are clearly not expected to last very long. In response to these changes in demand, the consumers’ group says, global supply is estimated to have fallen by 770 kbpd through the peak of the northern hemisphere’s summer driving season to just 91.59 mbpd, with the hit being taken by both OPEC and rival producers; there has been plenty of room for North American growth in the third quarter, its sources maintain. Near record Saudi output was needed in August to keep the market stable through the collapse in exports from Libya. By contrast “somewhat easier conditions in the fourth quarter” are expected, a reduction in Russian refinery runs being anticipated as overdue seasonal maintenance programmes are embarked on there.
Seasonal dip
‘Global crude supply looks set for an upward jump in [the fourth quarter]’ the Agency predicts. This is “Thanks to a heady mix of seasonal, cyclical, political and structural factors … New North American production continues to surge. Saudi production is hovering near record highs, even as a seasonal dip in domestic air-conditioning demand looks set to free up more barrels for export.” So all well and good then, except that in recent weeks Mediterranean refiners in particular have been scouring the market for a substitute for all those disrupted supplies from the Gulf of Sirte. Libyan output plunged to a post-war low of 150 kbpd at one point early in September (compared with a mean of 550 kbpd the month before)
And as to the short-term outlook for global oil demand the industrialised countries’ principal energy monitors say this is expected to average just under 91 mbpd for the current year as a whole, effectively precisely one percentage point up on the previous 12 months. ‘Growth is expected to accelerate in 2014 to around 1.1 mbpd [plus 1.2 per cent], lifting demand to 92.0 mbpd as the macroeconomic backdrop continues to improve.’ This trend had already been noted by the IMF in July and has just been confirmed in its latest quarterly forecast.
Longer term
But these are merely short-term factors and trends, the small change of the world’s largest commodity business. Most ADIPEC delegates know that much more is going on in the background, profoundly influencing the demand for oil, and possibly other energy products too, over the much longer term. This has already been seen in the slowdown in growth of global energy demand generally in 2012. For several years now nearly all the growth in global oil consumption has been taking place in the developing countries, in China and India in particular. Oil
Near record Saudi output was needed in August to keep the market stable
consumption in the traditionally 'rich' world (i.e. the OECD countries predominantly) seems to have peaked several years ago; overall all-forms energy consumption in these countries may have done so too. And there are some clear signs of demand in these countries coming down further in the years to come. First, the shale-gas bonanza in the United States is already displacing oil products from the nation’s mobile fuel tanks. Commercial vehicles have led the trend, but, as in Pakistan, US motorists are now starting to notice the advantages of compressed natural gas too. A regional and possibly global glut of gas seems to be on its way. Second, huge advances in engine design are advancing fuel consumption by 2-3 per cent per year for those automobile owners who update their vehicles regularly; even better is expected of the latest small diesels as vehicle weights drop dramatically. There’s no reason to suppose this change won’t affect countries like China, where stricter rules on kilometres per litre will be relatively easy to enforce. Use of gas is creeping into the design of ocean-going ships, and of railroad locomotives too. So the aviation industry is likely to remain as the sole unassailable bastion of rising oil consumption in terms of transportation technology. Third, most unconventional and ‘frontier’ oil – with the outstanding exception of the coming fracked supplies – continues to come out of the ground at a cost much higher than most conventional crude. The breakeven price for new Arctic oil is believed to now be very close to the cost of benchmark WTI today. Unless there’s a breakthrough in technologies including EOR this indicates that a supply constraint is on its way. That means higher prices and yet another slump in demand.
Secure future
Will the region experience a gas glut?
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Fourth, subsidy-aided renewables continue to storm the world, and in some countries like the UAE nuclear energy is growing fast, too. The result will be the displacing of more demand for oil. And finally, several of the world’s supermajors – and many NOCs too - are now relying increasingly on gas as the source of most of their future profits, aided by all those invaluable energy service companies which have mushroomed (like the independent oil drillers) in recent years. So the risks are being dispersed, with the Chinese taking on more and more in the world’s frontier territories. And the implications for ADIPEC attendees? A secure future most definitely, but don’t rely on oil alone for the next appointment after one. ■
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Oilfield services specialist ALMANSOORI SPECIALIZED ENGINEERING says it is the leading provider of oilfield services in the Middle East. Founded in Abu Dhabi in 1977, the company has grown to employ a workforce of more than 2,100 across 21 countries throughout the world. The company’s activities are predominantly based in the Middle East, although it is continually expanding its operations in North Africa, the Far East and Southeast Asia as well as North America and the North Sea region through a number of acquisitions and joint ventures with a number of internationally recognised companies. The company has enjoyed year-onyear growth in recent years, and has exceeded its 25 per cent growth target for 2013.
Optimising the approach to QHSE BUREAU VERITAS, A global leader in testing, inspection and certification of assets, systems, people and processes, will be on hand at ADIPEC to present its comprehensive offer of QHSE solutions for the oil and gas industry. Regionally headquartered in Abu Dhabi, and present throughout the UAE and wider Middle East, Bureau Veritas notes a strong and growing commitment to QHSE by Middle Eastern companies. Regional Chief Executive Marcel Hochar explained: “The Middle East is a world-leading region in the production and processing of oil, www.bureauveritas.com gas and petrochemicals. The high-risk nature of these industries has led companies to take a proactive approach to both the health and safety of their employees, and environmental protection. Bureau Veritas, already a major contributor to the regional and global energy industry, is working with most of its major companies to help them minimize risk and maximize performance in QHSE”.
Stand 9220B (Hall 9)
Italian expertise on show SIME SRL BEGAN operating in the oil and gas sector 24 years ago with an ambitious and dynamic engineering office. Today, the company says it has a dependable team of over 250 experienced specialists that offer engineering services of high quality and competitiveness. Sime is a privately owned Italian company with what it describes as a ‘flexible commercial approach’. With branch offices and strategic worldwide partnerships, its team covers a large range of services, from FEED to EPC and EPCm, modules and skid supply. Sime claims the successes that have been achieved over the years encouraged the company to the Abu Dhabi market, where they recently opened a new branch, thanks to the support of its local sponsor, Mohammed Al-Qubaisi Enterprises, LLC. Sime believe that experience and flexibility makes it a unique firm, capable of adding consistent value to your business.
Stand 12CN130 (Concourse)
www.almansoori.biz
PFS - meeting international standards
AlMansoori has seen a considerable increase in activity, especially in Abu Dhabi, and anticipates a major increase in oil and gas production – particularly within countries such as Saudi Arabia, Oman, Iraq and India. Testing and surveying have long been at the heart of the AlMansoori offering, with bottom hole pressure and temperature surveys, pipe management systems, technical auditing and magnetic particle inspection all key components of the company’s success to date. The firm has also invested in technologies which has allowed it to add drill stem testing, open hole logging and directional drilling services to its list of capabilities.
PFS TECHNOLOGIES (PFST) is a global provider of field solutions for oil and gas, refining, distribution, petrochemical, power, steel, and water applications. The company’s offerings include flow meters and monitors, as well as advanced compressed air foam (CAF) fire suppression solutions. The company’s meters and fire suppression products are designed to meet strict international standards and ISO 9001 compliance requirements for design, production and service. PSFT’s portfolio of clients in the region includes oil and gas majors, refineries, and petrochemical Flanged-end producers in Saudi Arabia, Iraq, UAE, Oman, Kuwait, as turbine meter well as the water markets in Egypt and Iraq. This local team works with customers to assess the right technology for their application requirements to deliver the most accurate and reliable flow metering and fire suppression solutions.
Stand 2410 (Hall 2)
Stand 12480 (Hall 12)
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Air pollution control WASTE GASES/AIR mixtures arise in virtually all production processes within the petrochemical industry, which have to be treated before they can be emitted into the environment as waste air. Only in this way is it possible to comply with the strict requirements for air pollution control. An efficient process for emission control is thermal incineration in which the polluted waste gases are successively incinerated. Special facilities are required for these complex incineration processes, where the formulation and the pollutant content of the combustion air fluctuates. Valves must not only be corrosion-resistant but must also be approved for potentially explosive areas according to ATEX and IECEx. UNI-Geräte has developed the appropriate Reliable solutions valve technology with which the incineration process can be safely handled even for difficult applications. The specialism of this valve manufacturer also involves finding reliable solutions where standard products are inadequate. UNI-Geräte presents at this year’s ADIPEC, together with its sales partners from the UAE, Kuwait, Oman and Qatar, a small selection from its multifarious range of precision products. Different variants of available valves will be presented to visitors by means of an exemplary safety control system with which numerous other applications can be handled. For over 60 years, UNI-Geräte has been a leading provider of high-grade quality electromagnetic and electro-pneumatic valves as well as of volume control fittings for liquid and gaseous fuels. With a network of sales partners on all continents, UNI-Geräte services over 3,000 customers worldwide who rely on the high quality and safety standards of products made in Germany.
Enhancing remote communications OFFSHORE AND ONSHORE accommodation specialist, HB Rentals, a Superior Energy Services company, recently launched HB DataMAX, a remote rig site communications service that offers solutions with faster speed, greater reliability and better call quality than previous technologies. HB DataMAX is at the forefront of enhancing communication across remote and varying terrain for drilling and production operations. Utilising the newest LTE technology, HB DataMAX operates at speeds faster than satellite communication with greater network redundancy and highly competitive rates. “HB DataMAX has been field-tested and is already being used in the Permian Basin and Eagle Ford shale plays, as well as areas throughout the Texas panhandle,” said Deidre Toups, president of HB Rentals. "We anticipate expanding this technology throughout the world as network providers expand their coverage.”
Network operations centre
Stand 8174 (Hall 8)
ADGAS wins IHS award ADGAS WAS RECENTLY awarded an IHS SPECTRUM Excellence Award for its sophisticated air emissions information system to strengthen and streamline its flaring handling and emissions reporting. With enterprise-level software, the company’s HSE experts have enhanced data management and reporting of daily flaring data, daily emissions, flare volumes and fuel gas data while also uncovering new operational The award was formally presented by IHS to ADGAS executives. efficiencies that save time and From left to right: Khalid Al Hadrami, Vice President of boost productivity. Information Technology; Namane Lecheheb, Head of Safety; Fahim ADCO was also recognized for Kazim, CEO; IHS executives Karim Cheikh-Ali and Chris Methven; an Excellence Award for Ahmed Al Mughanni, Head of Plant & Engineering Solutions developing and operating the Department; and Mohamed Zamzam, HSE Division Manager. leading-edge Health, Safety and Environment (HSE) Electronic Analysis Reporting and Tracking System (HEARTS). HEARTS provides capabilities to analyze incident/environmental data and to perform trend analysis, helping ADCO to manage its HSE Performance.
ADGAS - Stand A 20/A210 (Atrium) IHS - Stand 7525 (Hall 7) 130
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As the industry continues to focus on maximizing productivity, communication services are essential to maintaining an effective flow of communication. The more efficient the communication service (data, voice, video, Internet) the higher the rate of productivity for day-to-day decision making in remote operations. HB Rentals serves as a single-source provider for all communication needs – including traditional VSAT equipment, intercom systems and phone/fax lines – and has a support team in the field to ensure operators eliminate downtime dealing with communication challenges. HB Rentals is a leading supplier of temporary accommodations modules and related auxiliary equipment – including communication equipment and services – serving remote onshore and offshore project sites globally.
Stand 4410 (Hall 4)
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Investing in regional heat exchanger growth MOTHERWELL BRIDGE IS Investing to spearhead its growth in the Middle East heat exchanger repair and new-build market based in Abu Dhabi. The move will see heat exchanger specialist Mahesh Pai appointed as divisional head, effective immediately. Based in Abu Dhabi, Mahesh joins the company from onshore and offshore fabrication specialists Adyard formerly part of oilfield services group, Topaz Energy and Marine. Motherwell Bridge regards the Middle East as key to its ambitious business expansion strategy and the appointment will enable the company to respond to increasing enquiries for its full suite of heat exchanger services in the region. The region is seen as a vital growth area for Motherwell Bridge and it is anticipated the region will account for around 35 per cent of divisional turnover by 2016. Motherwell Bridge chief executive Russell Ward said: “Mahesh’s appointment is a direct result of increasing demand for our services in the region. “To date, we have taken a pragmatic approach to business development in the Middle East, derisking in this challenging environment by teaming up with people who know the market.
Ready for regional expansion “With significant experience in managing projects in the sector and the region, Mahesh will be our man on the ground, well resourced to allow these initiatives to hit the ground running. “While we have been growing our presence here for some time, the launch of a dedicated heat exchanger division demonstrates our continuing commitment to tapping into Middle East contracts.”
Samson to show its strengths GERMAN FIRM SAMSON Controls has developed its control valves, positioners and accessories alongside the major European giants in the chemical and petrochemical fields and has been supporting the GCC oil & gas industry since the establishment of its Jebel Ali subsidiary in 2009. The regional move in the direction of energy efficiency, renewable energy and downstream oil & gas production requires products and skills which Samson is not only familiar with but very much at home too. The company’s product portfolio ranges from valves and accessories for severe service applications (including special materials) to cost-effective standard equipment.
Stand 5210/5220 (Hall 5)
Innovations from Emerson EMERSON PROCESS MANAGEMENT will highlight its innovative technology solutions for the oil and gas industry ADIPEC. Emerson’s oil and gas experts from the Middle East and abroad will engage attendees in technology demonstrations and discussions on everything about process automation, from onshore and offshore project engineering, to well planning and construction, to process enhancements and fiscal metering. Emerson has been impressed at the event’s success of bringing industry experts under one roof to interact and share knowledge and experiences. Emerson’s interactive exhibition stand will present field and plant environments featuring wellhead instruments, multiport flow selectors, multiphase flow meters, custody transfer systems, and process control and safety systems. Visitors will be able to touch and experience these technologies and learn how these can make their processes on line faster and easier, improve operational efficiency, and optimise production. At time when Middle East's oil and gas landscape is evolving fast and presenting new challenges, producers are turning to operational and maintenance improvements through technology innovations. Emerson’s industry experts will be on hand to listen to customers, from technicians who work daily in fields and refineries to top level managers who make crucial business Emerson will have experts on hand decisions. Emerson has been working with major oil and gas producers in the region for nearly two decades. It operates a network of sales, manufacturing and service facilities in the region, working close to customer sites to provide world class local support and services. The facilities are located in Dubai and Abu Dhabi, Doha and Ras Laffan in Qatar, Kuwait City in Kuwait, Basra in Iraq, Manama in Bahrain, and Al Khobar and Jubail in Saudi Arabia.
Most of the company’s control valves and accessories are developed and manufactured at its headquarters located in Frankfurt am Main, Germany. The company says in-house manufacturing ensures highest product quality and reliability.
Stand 4338 (Hall 4)
Stand 8264 (Hall 8)
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Al Falih - all sources of energy needed to meet future demand
Demand is expected to be substantially higher by 2050
Al-Falih - inspirational opportunity ALL SOURCES OF energy – with oil and gas at the core -- will be needed to meet the rapid increase in world energy demand by 2050, Khalid A. Al-Falih, president and CEO, Saudi Aramco, said recently in the opening keynote address at the World Energy Congress (WEC) 2013 in Daegu, Korea. In line with the WEC theme Securing Tomorrow’s Energy Today , Al-Falih said the energy industry is healthier and more dynamic than before, but still faced a historic challenge to provide ready access to clean energy, particularly for billions of people around the world trapped in energy poverty. With the world population projected to increase by between two billion and nine billion by 2050, and the global economy expected to be three or even four times larger, energy consumption is certain to rise significantly.
Supply challenge
“We need all energy sources; all industry players; all governments; all academic and research institutions; and all energy bodies, working together in the global energy village,” Al-Falih said “And nine billion people will have the energy they need and so well deserved to prosper.” Even with advanced energy management and efficiency programs that could lower consumption, demand is expected to be substantially higher by 2050 with the world’s rising population empowered by prosperity, he said. Helping to meet the future supply 134
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challenge will be the abundant availability of oil and gas, which, Al-Falih emphasized, will remain the core source of energy to the world. Saudi Aramco is working on increasing conventional oil recoveries to 70 per cent, which is more than double the current world average, and discovering large, untapped oil and gas resources, both onshore and offshore, and both conventional and unconventional, Al-Falih said. “In fact, I’m delighted to announce that two years after launching our unconventional gas program in northern Saudi Arabia, we are ready to develop a 1,000-megawatt power plant, which will feed a massive phosphate mining and manufacturing center and drive that region’s development and the prosperity of its people.” However, Al-Falih urged prudence in the use of oil and gas resources, which “are the crown jewels of current and future energy supplies”, and called on the industry to improve their efficiency and environmental performance, and extend their use by combining them appropriately into the energy mix with other sources. In his address, Al-Falih said that while nuclear, coal, alternatives and renewables have their challenges and limitations, these energy sources will unquestionably have a role to play in meeting the world’s future energy supply challenge.
Full potential
In Saudi Arabia, the Kingdom is embarking on a vision to become a global hub of solar
energy, and urged the energy industry to come together and unleash the full potential of alternatives and renewables. Ultimately, the appropriate energy mix should be left for the market and technology to determine, Al-Falih said. But with the projected increase in the world population and ensuing demand, Al-Falih said there is room for everyone in the energy industry to prosper “under one roof”. He then went on to outline four prerequisites for success: pragmatic global energy policies; long term industry investment; R&D and technology; collaboration. A stable economic environment and market certainty is critical to ensure long term investment by the industry, he said, adding that Saudi Aramco has made massive investments to create and maintain the world’s largest spare oil production capacity of more than two million barrels per day.
Opportunity
“In the past two years alone, we have swung our production by more than 1.5mn barrels a day in order to meet market supply imbalances and retain that vital market stability the world needs,” Al-Falih said. Pointing to the future, Al-Falih said in concluding his remarks: “Providing adequate, affordable, and acceptable energy to nine billion people will be the challenge of our lives, and of those who will follow in our footsteps. But it also presents us all with the most inspirational opportunity.”
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3D Plant design and Information management Cadmatic Ltd is a leading developer and supplier of 3D plant and ship design software and engineering data management solutions for industrial projects. The companyâ&#x20AC;&#x2122;s growing list of customers includes over XVHUV LQ FRXQWULHV ZRUOGZLGH WKDW DUH VXSSRUWHG E\ FHUWLÂżHG sales and support centers in over 20 countries around the world. &DGPDWLF //& *&& $UHD 2IĂ&#x20AC;FH 2IÂżFH %XVLQHVV 9HQXH %OGJ 2XG 0HWKD 5RDG 3 2 %R[ 'XEDL 8$( 7HO 0RE umesh.angadi@cadmatic.com Cadmatic Ltd, Headquarters ,WlLQHQ 5DQWDNDWX 7XUNX )LQODQG WHO VDOHV#FDGPDWLF FRP
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First ever ADIPEC business
conference scheduled This year’s event will include a business conference that will bring together the entire gas and oil strategic value chains for the first time.
Industry strategies will be discussed
T
HE BUSINESS CONFERENCE will take place on the first two days of the main exhibition and conference. Through a series of panel sessions and strategic presentations, where delegates and global industry leaders will share knowledge and experience, the business conference will explore a range of commercial topics, including the successful monetisation of new global gas and oil frontiers on the East African continent, Central Asia and Australia, through to future Indian and Chinese oil demands, Iraq’s potential to be a game changer for global oil production and mature gas field management strategies in the Middle East and further afield.
A number of global and regional business leaders and government ministers are set to speak at the conference In addition, experts from the world’s largest gas and oil companies will debate issues related to the development of a global energy workforce, focussing on topics such as succession planning, employee retention, and creating and increasing in-country value. Mohammed A. Sahoo AlSuwaidi, Director, Gas Directorate – ADNOC, Chairman –ADIPEC 2013 Conference, said: “The business conference is a critical new addition to what is the biggest hydrocarbon event in the region. With the business landscape for gas and oil undergoing a phase of evolution, the creation of a platform that allows for knowledge transfer between leading industry strategists will enable businesses to stay 136
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ahead of the curve and maximise potential opportunities. “Several high-profiled and respected international CEOs have already confirmed participation in the discussions and we are confident that the business conference will serve as one of the most important components of this year’s ADIPEC.” A ministerial panel, at which policy leaders will debate topics such as future energy security and the need for robust domestic energy policies to stabilise local supply with international demand, underscores the importance of the conference and of Abu Dhabi’s role as both a global energy hub, and a seat of intellectual debate for the industry’s most influential executives. A number of global and regional business leaders and government ministers are set to speak at the conference. The global executives already confirmed to participate are: • Bob Dudley, CEO, BP • Toshiaki Kitamura, President and CEO, International Petroleum Exploration Corporation (INPEX) • Hirobumi Kawano, President, Japan Oil, Gas Metals National Corporation (JOGMEC) • Moon Kyu Suh, President and CEO, Korea
National Oil Company (KNOC) • Maurizio La Noce, CEO, Mubadala Petroleum • Yousuf Al Ojaili, CEO, Oman Gas Company (OGC) • Ayman Asfari, Group Chief Executive, PETROFAC • Igor Sechin, President and CEO, ROSNEFT • Peter Voser, CEO, Royal Dutch Shell • Abdelhamid Zerguine, CEO, SONATRACH • Helge Lund, CEO, Statoil • Carl Sheldon, CEO, Abu Dhabi National Energy Company (TAQA) • Christophe de Margerie, CEO, TOTAL Claire Pallen, ADIPEC 2013 conference director, said: “The Middle East is an international focal point for the hydrocarbon industry – a fact that is reflected in the strong attendance list for our first business conference. However, given the commonality of the business challenges and opportunities, the content of the discussions will be entirely relevant to industry executives and policy makers from all markets across the world. “We look forward to meaningful discussions that offer global decision makers a competitive advantage and we urge regional decision makers and industry professionals to participate in this important debate.” ■
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Integrity of
offshore structures Atkins & ADMA-OPCO* look at the state of the art for assessment of the integrity of offshore structures.
L
IFE EXTENSION AND associated brownfield projects are increasingly being applied to fixed offshore structures across the globe. Evaluation of the integrity of an offshore structure is one of the four key functions of an integrity management system â&#x20AC;&#x201C; the others being acquisition and management of data; strategy for in-service inspection, mitigation and/or early decommissioning; and programme for in-service inspection. Evaluation requires assessment if an initiator is triggered such as development projects on existing installations, when new Metocean or Geotechnical information becomes available and, for older assets, to ensure that degradation due to fatigue, corrosion and seabed settlement from reservoir compaction is acceptable. Development projects on fixed installations typically involve a significant
increase in topside weight due to new process facilities together with increased wave load due to new risers or conductors. Also, the quantity of metocean data and quality of data processing and modelling has increased significantly in some geographic regions and has resulted in more accurate estimates of wave heights in extreme storms that may result in an increase from previous less accurate estimates. The latest computer simulation techniques (such as ultimate strength analysis using software such as ABAQUS [1] with the critical components of the structure represented in detail and embedded within the model of the total structure in order to provide the correct boundary conditions) usually demonstrate the structure has greater capacity than shown using previously adopted techniques. Atkins and ADMA-OPCO have also developed computer
simulation techniques that allow the stress due to loads added after previous strengthening to be correctly assessed and typically show that although the original steel may develop plastic strain (when a factor of safety of 1.0 is applied), these strains are limited to permissible levels by the new strengthening steel that remains elastic at a factor of safety of 1.0. The figure below shows a computer model of one of ADMA-OPCOâ&#x20AC;&#x2122;s bridges on the Zakum field that had a recent project requirement for additional load but had previously been subjected to strengthening and load increases. The embedded detailed models of the joints show that the plastic strains (at the factored load) are small and acceptable thus demonstrating that the bridge can meet the requirements of ISO 19902 with the additional load.
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The ISO [2] standards for offshore structures are currently being updated and one of the outcomes is likely to be greater consistency in the assessment methodology and criteria required for the integrity of offshore structures in all regions of the globe. Recent assessments of fixed offshore structures by Atkins in the Arabian Gulf, North Sea, Gulf of Mexico, Caspian Sea and NW Shelf have indicated that to achieve greater consistency: • The industry needs to set Acceptance Criteria based on reliability studies, structural performance around the globe and experience. The criteria need to be straightforward and limited to linear and non-linear methods of analyses and software. Good guidance is required in the codes to allow most engineering contractors to do good work. This guidance should focus on
Development projects on fixed installations typically involve a significant increase in topside weight the structural modelling; loading model and material behaviour in component design versus system ultimate capacity checks. • Engineers performing structural assessments require a deeper understanding of the assessment methods used by Metocean consultants and Geotechnical engineers. Atkins has successfully applied the above methodology to the assessment of jacket structures in many global regions. Although
some further work is required to establish complete consistency across all regions, the next revision of the ISO code may well achieve this. ■
*Dr Ramsay Fraser – Atkins Oil & Gas, Mr Hisham Awda – ADMA-OPCO, Dr Amr Azouz – ADMA-OPCO Acknowledgments: This article is based on technical developments by Atkins’ offshore structures team in the UAE. Also, ADMA-OPCO structures team has shared relevant data for this article with Atkins. [1] ABAQUS Software, Dassault Systèmes Simulia Corp., Providence, RI, USA. [2] ISO 19902, Petroleum and natural gas industries - Fixed steel offshore structures 2007 Stand 8225 (Hall 8)
UAE still a key market for Hi-Force applications involving multiple Hi-Force HI-FORCE HAS HAD a presence in the UAE An aerial view of the Hi-Force facility high tonnage cylinders, pumps, hoses since 1992 when its first Middle Eastern and logistics center in the UK and accessories. The Hi-Force facility opened in Jebel Ali Freezone, Dubai. philosophy of offering a complete Kevin Brown, now group managing service package to support its valued director, headed up the move as part of a customers needs and requirements also global expansion plan originating from the extends to tool rental services. With UK headquarters. such an extensive array of products Following the immediate success of Hiwithin the Hi-Force range, it is Force FZCO in Dubai, a further facility was sometimes difficult for customers to later opened in 1996 in Mussaffah Industrial decide on the most suitable tool in which area of Abu Dhabi. Since then, Hi-Force’s to invest their money. Additionally, some operations within the UAE have steadily customers simply cannot justify the capital outlay to purchase developed and funded further developments for the company. higher value products, such as high tonnage cylinders, powered According to a company statement, Hi-Force is the UK’s leading manufacturer and supplier of hydraulic tools and offers an extensive pumps, hydraulic wrenches, stud bolt tensioners and hydrotest pumps, especially in cases where their needs for the product are product range from cylinders, manual and powered pumps, manual relatively short term or simply for a one-off job. and hydraulic torque wrenches, stud bolt tensioners, jacks, nut splitters, puller kits, crimpers and many other industry specific tools. The oil and gas industry has been the largest sector for Hi-Force since the company established itself in the region. Although the As a result, its customers and their industries include; oil & gas, recent economic downturn led to reductions in activity within the petrochemicals & refining, shipbuilding and ship repair, aerospace, industry, a recovery in the market is reflected through increased defence, heavy engineering and the many thousands of industrial activity at Hi-Force. The company’s Abu Dhabi branch has service company’s supporting these industries. However, in the UAE experienced a significant increase in performance over the last 12the oil and gas industry forms the majority of the company’s 18 months. In the future, the oil and gas industry will be at the customer base for the region. In addition to forefront of the company’s strategy and will remain a key market for the extensive range of products, Hi-Force Hi-Force for many years to come. Globally, Hi-Force is continually also offers an excellent and highly expanding and this will continue into the future. The group hopes to reputable on-site service. Through open new regional offices around the world. Due to this global training, years of experience and expansion, the UK head office has recently taken delivery of a new a motivated workforce, Hi-Force multi-million pound purpose built facility, at the rear of the existing is able to offer an on-site service UK manufacturing plant to cope with the increased demand for that is says is second to none. Its product worldwide. The new facility comprises of almost 20,000 on-site services include bolting square feet of built up area, plus an additional 15,000 square feet of services, from a simple bolt up of secure yard area and houses the complete UK logistical operation a single flange joint to major from raw materials through to finished product, plus a 1,500 square construction and maintenance The Hi-Force TWS370N square drive and shut down projects, to on- feet ECITB approved Training School. hydraulic torque wrench – just one of the many Hi-Force products to be site lifting and jacking services usually related to heavy lift Stand 240 (Hall 2) displayed at Adipec 2013’ 138
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SAOGE Date: 25th-27th November, 2013 Venue: Dhahran International Exhibitions Centre
Eastern province open to oil
and gas visitors again A key energy-business exhibition opens in Dammam on 25 November. Attendance is expected to be up once again; this is a very popular annual event which always attracts interest from far beyond the Kingdom's borders.
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AST YEAR’S SAOGE brought in nearly 8,000 visitors, representing steady growth since the exhibition series was launched by Dhahran International Exhibitions Co back in 2007. The whole event’s key sponsors were Abdulla Fouad Holding Co, Al Abdulkarim Holding Co, SABIC and Industrialisation & Energy Services Co (TAQA). With crude oil prices (industry-benchmark WTI) staying well above US$100 for many months now and Saudi Arabia alone holding one-fifth of the world’s proven reserves the Kingdom remains the number-one magnet for energy industry suppliers. The more recent renewed search for non-associated gas and unconventional supplies of both just makes the attraction stronger; the funds to pay for the development of it all and in the process to build the “World’s energy capital” show no sign of being diminished.
Magnet
SAOGE itself is the key event that brings industry leaders from home and abroad together under one roof in the energy-rich
Province to form and strengthen business relationships and to identify new projects and opportunities. Saudi Arabia is also a top magnet for foreign direct investment in industrial development generally, at a time when few opportunities elsewhere are anything like as large – or as secure. Organised as usual in association with International Exhibition Services of Rome this will be the fifth edition of the Saudi Arabia International Oil & Gas Exhibition, an event which always attracts strong overseas support from major companies headquartered in China, Germany, India, the
SAOGE itself is the key event that brings industry leaders from home and abroad together under one roof
USA and many other countries, as well as local suppliers from throughout the Gulf of course. In 2012 there were more than 150 exhibiting businesses and institutions in total present in Dammam, more than half of them visiting from outside Saudi Arabia. Typically two-thirds of the attendees themselves come from Saudi Arabia, this being not just the Eastern Province’s but also the Kingdom’s leading oil and gas event. The whole exhibition, running from 25-27 November, is again being supported by the Bilateral US-Arab Chamber of Commerce; the Saudi Arabian Section of the American Institute of Chemical Engineers is also backing the event, including the associated Student Programme (see below). ‘Oil Review’ is delighted to have again been appointed Official Publication for such a successful and prestigious event.
Local talent
Once again a special programme to attract local industry and business trainees is being incorporated into the organisers’ plans, with the support of both the King Fahd University of Petroleum and Minerals and the University of Dammam. The purpose is once again to support the development of local talent for the benefit of the Kingdom’s energy and associated industries generally. For the third time SAOGE 2013 with its associated social events will be providing an excellent opportunity to local, regional and
The Kingdom’s resources are a magnet for energy industry suppliers
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overseas companies and institutions to explore the countless business opportunities currently - and for the foreseeable future being presented by this huge industry concentrated so heavily in the Kingdom’s Eastern Province. ■
Typically two-thirds of the attendees themselves come from Saudi Arabia
On last year’s event “We look at SAOGE as a very important platform for the Saudi Arabian oil and gas business” Abdulla Al Dossary, Group Marketing Manager, Abdulla Fouad Holding Co
“We found the show very useful this year; it is a good opportunity to meet all our customers, to meet trading partners from Saudi, the Gulf region, and overseas” Brian Sullivan, General Manager, Alaa for Industry
“The quality of the attendees and exhibitors is very good” Abdulaziz A Al Abdulkarim, Vice Chairman, Al Abdulkarim Holding Co
“This exhibition has a great influence in the Saudi market. We have already decided to take part at the exhibition in 2013” Lu Yuan, Manager KSA, CPTDC www.saoge.org
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Technology
The cost of corrosion in the
offshore industry
Andrew Courtney of Surface Technology, part of Norman Hay plc and a global industry leader in specialist engineered surface coatings, looks at the issue of corrosion and the preventative steps that can be taken in component design, specification and manufacture. He will also explain how minimising corrosion can optimise component performance and reliability, significantly reducing operational downtime in critical offshore applications.
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ETAL CORROSION IS a costly fact of life in the oil and gas industry. Surface deterioration of the metal components used in offshore production processes can lead to premature and often sudden failure with the risk of costly, unscheduled downtime and the threat of hydrocarbon leaks. Corrosion can be defined as the gradual destruction of materials by chemical reaction with their environment. According to the United States Cost of Corrosion Study, produced by NACE International, one of the world’s leading authorities on corrosion engineering and control, corrosion costs the US oil and gas exploration and production industry US$1.4bn a year. To put the cost of corrosion to the offshore industry in closer perspective, as far back as 2000, retrospective bolt preservation on each of its North Sea assets accounted for costs of between US$242,000 and US$400,000. For oil and gas producing operations, there is no escaping the challenge of corrosion; steel is susceptible to corrosion and the harsher the environment, the more accelerated the corrosion process becomes. As offshore exploration moves into deeper and more hostile waters, so the potential impact of corrosion increases. The greater difficulty maintaining components in increasingly remote and challenging environments requires the need for extended component life. Components which have enhanced resistance to the effects of corrosion are now essential as they increase service life and reduce the need for costly maintenance. Developments within the industry, aimed at reducing offshore development costs, involve reduction in platform weight and increasing use of satellite wells and subsea manifolds, all of which require specific attention to corrosion prevention.
Any surface deterioration on the metal products used in key applications can lead to premature and often sudden failure. In addition to corrosion, wear is another factor, typically from abrasion and impact, and
Benefits include improved wear resistance and lower friction, leading to improved abrasion resistance
while each is damaging enough on their own, they can combine to cause aggressive damage – pitting, roughening, grooves, dents, cavitation and cracking to name but a few. Individually, corrosion and wear are problematic, combined the sum can be greater than the parts. In offshore oilfields, metal structures and components are under constant attack from a variety of sources from drilling muds to water and carbon dioxide to acid. Much metal loss in oilfield casings is caused by crevice corrosion. Although corrosion will initially be uniform across the surface area of the metal, in time it will accelerate in any
The application of corrosionresistant coatings is perhaps the most widely used way of protecting steel
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small crevice in the metal. Crevice corrosion often starts at drill-point joints, tubing or casing collars. Pitting equally causes vulnerability when a small scratch, impurity or deformity in the metal can start the corrosion process. Corrosion that starts with pitting can ultimately progress into cracks in the metal, which can be accelerated by tensile stress, resulting in stress corrosion. Corrosion fatigue, when metals are subjected to alternating stresses in a corrosive environment, can affect all types of welded connections on drill ships, drilling and production rigs and platforms. With an issue as significant in terms of both cost and productivity, we cannot afford to think in terms of rectification. We are, instead, looking at surface engineering – the treatment of material surfaces to change their properties or characteristics to achieve improvements in performance - eliminating corrosion by design. When considering offshore and sub-sea components, engineered surface coating solutions can be employed to achieve, amongst other things, improved corrosion and wear resistance. As such, it is a discipline that should be applied throughout the design, specification and manufacturing process as an integral part of
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For oil and gas producing operations, there is no escaping the challenge of corrosion
Andrew Courtney component development to ensure that the specific needs of the operational environment are addressed. While corrosion is inevitable, it can be inhibited by the application of specialist engineered coating solutions to extend the
service life of components and control maintenance costs. Steps taken at the product finishing stage will minimise the risk and effects of corrosion and so optimise performance and longevity. Although there are a number of options, including changing the environment by the use of inhibitors, cathodic and anodic protection – even using more highly alloyed specialist stainless steels – the application of corrosion-resistant coatings is perhaps the most widely used way of protecting steel. The choice of coatings includes organic, metallic or inorganic and there is a wide variety to choose from. Specialist engineered coating solutions can address issues of corrosion, gall resistance or fouling problems. Applications typically include Christmas trees, subsea connectors and seals, riser systems, clamps,
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seat, seals and valves, hangers, threaded components such as nuts and bolts, as well as manifolds and valve bodies. Thermal spray coatings exhibit high resistance to corrosion and wear in extreme applications and are increasingly being used in the oil and gas industry. The use of thermal spray to apply coatings, such as High Velocity Oxy Fuel (HVOF), is one of the most commercially viable and allows the control of various parameters including powder particle velocity and temperature, which influence coating properties such as residual stress, bond coat strength and microstructure. Another coating system used to provide corrosion resistance, often to offshore structures on-site, is Wire Arc spraying. Wire-Arc thermal sprays provide a dense and strong metal coating and they are an excellent choice for protection against corrosion. Galvanically active coatings such as Zinc and Aluminium can be applied using the Wire-Arc process. The Wire-Arc process involves two wires that are driven into an electric arc to form molten particles of spray and are forced out of the gun by compressed air onto the substrate. The Wire-Arc spray process is known as a 'cold' procedure, as the substrate temperature can be kept low throughout. Wire-Arc metal spraying is also used to apply non-slip coatings to protect both infrastructure and employees and is typically applied to walkways and tread plates. Thermal Spray Aluminium (TSA) is also applied using a wire-arc spray gun. Fluoropolymer coatings are a blend of high performance resins and fluoropolymer lubricants, such as polytetrafluoroethylene (PTFE). This type of coating offers a superior dry film lubricant that produces a smooth, hard, slick surface and provides excellent corrosion and chemical resistance, often used to meet the environmental demands within the offshore oil and gas industry. Fasteners are particularly suited to PTFE coating, with its ability to provide a combination of high corrosion resistance combined with accurate torque loadings. Well head equipment operating under extreme conditions can also take advantage of PTFE high performance coatings, both for corrosion resistance and its load bearing and release properties. Armourcote is an engineered coating solution developed by global leader in specialist surface coatings for the oil and gas industry, Surface Technology, to inhibit corrosion and provide surface release for marine equipment. The brand was originally established with the introduction of proprietary composite coating systems developed to overcome the inherent softness of the materials used for surface release and friction control applications. 146
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These composites were first developed using fluorocarbon and fluoropolymer coatings and have subsequently been extended to include high load bearing, high temperature precision deposited dry film lubricants.
Another coating system used to provide corrosion resistance, often to offshore structures on-site, is Wire Arc spraying Benefits include improved wear resistance and lower friction, leading to improved abrasion resistance. Loads are taken up by the reinforcement peaks and any wear and abrasion that occurs exposes more of the fluoropolymer coating. The peaks of reinforcement are continuously smeared with the coating, which results in a smooth wear and abrasion-resistant, lowfriction finish. Where greater levels of corrosion protection are necessary for operations in hostile and demanding environments advanced multi coat, anti-corrosion paint systems are often specified, which complement other protective surface coatings to overcome these serious situations. The anti-corrosive qualities of epoxy paint systems make them suitable for providing marine barrier protection on subsea equipment that will be permanently immersed or in the splash-zone. Epoxy systems are also resistant to chemical attack, making them useful on equipment such as pipelines and chemical tanks.
The oil and gas industry has wellestablished processes which have been used for many years to provide high levels of corrosion resistance. Surface Technology facilities in key oil and gas manufacturing and production areas in the UK, Australia, Malaysia and Dubai are able to support the industry with dedicated application knowledge and expertise across the full range of coatings used in the industry. This ability to offer finishes including thermal spray coatings, engineered coatings and anti-corrosion paint systems in conjunction with surface preparation and finishing, gives our customers a “one stop shop” for their entire surface finishing needs. Our experienced, skilled and qualified workforce applies these finishes in strict adherence to the specifications and quality assurance requirements demanded by our customers. We inspect and ensure that our work complies with the requirements of Norsok, NACE and ICORR as expected by customers in this industry. With an ageing asset infrastructure, a constant need to improve productivity and a move towards increasingly hostile production environments, preventing corrosion is vital in every step of the offshore oil and gas production industry. Having more than 50 years’ experience serving this market globally, providing a complete range of engineered surface coatings combined with extensive technical knowledge and application advice, Surface Technology is well placed to help the industry mitigate the threat of corrosion and meet its key challenges of extending equipment life, reducing downtime and reducing operating costs. ■
Crevice corrosion often starts at drill-point joints, tubing or casing collars
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RELIABILITY IN OIL WELL CEMENTS Oil Well Cement (OWC) produced by Oman Cement Company (S.A.O.G) under accurate temperatures is an obvious choice for oil well cementing worldwide and now it is ready to face the challenges of highly specialized arctic and horizontal cementing: ● Conforms to the American Petroleum Institute (API) specification – 10A Class-G- (HSR), Class-B- (HSR) and Class-A- (O) grades. ● Tested and used by worldwide cementing companies ● Easy to disperse resulting in considerable cost savings ● First choice of major oilfield companies ● Exported to GC Countries, Iraq, Yemen, Libya, Sudan, Tanzania, Turkmenistan, Ethiopia, Pakistan, India and Syria. Oman Cement manufacturing facility operates on world class quality management system ISO 9001 and environmental management system ISO 14001. Quality control is online and laboratory automation systems consist of online x-ray spectrometers and robotic samplers, linked to process controllers and a raw mill proportioning system. OCC has an enduring commitment to customer satisfaction, continual improvement and a stronger foundation for tomorrow. Winner of His Majesty’s Cup for the Best Five Factories in the Sultanate of Oman for 10 times.
CERTIFIED CO CERT NO. IND13.3020/U/Q
CERTIFIED CO CERT NO. IND10.7570 API CERTIFIED CO LICENSE NO. 10A-0059
Oman Cement Company (S.A.O.G) Corporate Office: PO Box 560, Ruwi, PC 112, Sultanate of Oman Tel: +968 24437070 Marketing: Ext 145 / 444 Fax: +968 24437799 Email: admin@omancement.com Website: www.omancement.com
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Technology
Integrity management: reducing
hydrocarbon releases Hydrocarbon releases (HCR’s) have long been a hazard to offshore operations, as Ben Coutts* explains.
N
OT ONLY DO HCR’s represent a potential precursor to major accidents and cause unplanned shutdowns and asset downtime, they are also a key indicator of the effectiveness of asset integrity management across the industry. In 2010 the Health and Safety Executive’s (HSE) Offshore Division (OSD) launched their strategy for Key Programme 4 (KP4), the Ageing and Life Extension (ALE) Inspection Programme. The ALE Inspection Programme aims to promote awareness and management of the risks associated with ageing plants in the offshore oil and gas industry in support of four identified priority areas - asset integrity, competence, safety culture and leadership. In support of this, the Step Change in Safety group, comprising of senior managers and officials from member companies, industry-related trade associations, trades unions and the HSE, introduced a target for a 50 per cent reduction in HCR’s by the end of March 2013.
Key element
Although reductions in HCR’s have been achieved in the last few years; fluid connectors, hose and small bore tubing (SBT) combined, accounted for 27 per cent of unplanned HCR’s between 2008 and October 2010 (source: SPE 145449). The oil and gas industry has focused on these areas as a key element of KP4 and Hydrasun, in conjunction with operators, service companies and industry bodies has been at the forefront of implementing initiatives and programmes to further reduce the instances of HCR’s. This includes developing and carrying out robust planned maintenance and inspection routines, participating in the Energy Institute’s steering groups in the development of revised integrity management guidelines for 148
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Effective integrity management of hose and SBT assemblies is essential to successfully reducing HCR’s both hose and SBT assemblies, and with the Step Change in Safety group in developing an ECITB accredited qualification in SBT. Hydrasun identified the need for an even sharper focus in the integrity management of hose assemblies, and in particular SBT and instrumentation assemblies, following research that identified the key contributors’ to HCR’s to be incorrectly fitted equipment, improper operation and non-compliance with existing procedures - mainly human factor related issues and incorrectly specified equipment. Simplifying SBT assemblies wherever possible can reduce complexity, leak paths, human error and NPT threaded connections. Hydrasun has implemented an alternative
Hydrasun’s engineers proposed an innovative approach incorporating the latest emission reducing technologies
and innovative approach to the traditional methods associated with the design and management of instrumentation systems; developing a portfolio of the latest technologies, combining them with enhanced training, competency assessment and integrity management programmes. Through this alternative methodology, leak paths are engineered out of systems and the likelihood of human factor issues contributing to HCR’s is also greatly reduced. Effective integrity management of hose and SBT assemblies is essential to successfully reducing HCR’s. Hydrasun’s established hose integrity and SBT management philosophies, in conjunction with industry initiatives, have been an important factor in reducing instances of HCR’s and other emissions from Flexible Hose Assemblies (FHA’s) and SBT across the UK Continental Shelf (UKCS).
Integrity
In addition, competent personnel are vital to assuring the effective integrity management of fluid power, process control, instrumentation and hydraulic system hose
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With experience spanning across the trading, engineering, contracting, production and technology services platforms, Saudi Arabia’s Al-Bassam Group of Companies aims to be your company of choice in the oil and gas industry. Some of our renowned offshoots in the market are certified by international governing bodies and our major clients include Saudi Aramco and SABIC. Techno Serve, that manufactures gear like drilling equipment, threaded companion flanges and weld neck, is licensed by the American Petroleum Ins tute (API). It has catered to renowned companies like Saudi Aramco. h p://technoserveco.com
Gulf Heavy Industries, an ISO 9001-2000 cer fied company, is a producer of equipment such as pressure vessels, columns, reactors, boilers, driers, silos, storage tanks and piping for oil and gas and chemicals and petrochemicals plants. h p://ghi.com.sa
The Industrial Support Services-Non Destruc ve Tes ng (ISS NDT) unit offers all types of inspec on and NDT services that include radiographic tes ng, magne c par cle tes ng and leak detec on. This unit has clients like Saudi Aramco, Saudi Chevron and Saudi Electric in the por olio. h p://www.albassamgroups.com/iss/services.htm
Industrial Support Services, The Lab is an ISO/IEC cer fied and SASO accredited tes ng centre that caters to companies engaged in petroleum, environmental, water, agriculture, metallurgy and construc on materials sectors in Saudi Arabia. h p://www.issndt.com.sa
Al-Bassam Petroleum Equipment Company (APECO) that was set up more than five decades ago, established its foothold in trading, engineering and contrac ng. The unit is a major supplier of equipment like tubing and casing, drill pipes, down hole gauges, flanges and fi ngs to Saudi Aramco and SABIC. h p://www.albassamgroups.com/apeco/index.htm
AL-BASSAM GROUP OF COMPANIES P.O. Box No 2611, Dammam 31461, Kingdom of Saudi Arabia, Tel: +966 13 8051313, Fax: +966 13 8053110 Web: www.albassamgroups.com
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and SBT assemblies. Hydrasun utilises its OPITO accredited and ECITB approved Learning and Development programmes to ensure personnel are fully trained in the technical and other core skills required to deliver against the industry’s and the HSE’s demanding requirements. Another key element of integrity management is to ensure survey data collected during inspections for reporting FHA and SBT condition, compliance and recommendations for remedial action, are effectively stored, communicated and readily accessible. To meet these requirements, Hydrasun developed a secure, web based information system ‘Hydralink’, which holds customer’s survey data centrally. It has proven to be very effective, providing customers with key performance indicators and information
that can be used in their integrity management programmes and planned maintenance routines.
Benefits
One of the world's leading international oil and gas operators demonstrated its commitment to alleviating the risks of HCR’s on a current major project, through adopting a Hydrasun led initiative in reducing leak paths, and NPT threads, on all SBT assemblies and instrumentation hook-ups wherever practicable. Hydrasun’s engineers proposed an innovative approach incorporating the latest emission reducing technologies, and a robust programme of training, competency assessment and inspection services. Through Hydrasun’s management of these aspects of the project, across all Package
Ben Coutts
Vendors, a consistent approach was implemented and has already delivered significant benefits over traditional control and instrumentation application engineering methods. There are significant operational and commercial benefits to the industry in delivering long-term safety, integrity and reliability assurance of instrumentation systems and SBT assemblies. A modest reduction of 250 fluid connections per asset in the UKCS, would represent around 72,000 fewer leak paths in our sector. Therefore, the focus on achieving continued reductions in HCR’s must remain at the forefront of our Industry’s priorities. ■
Hydrasun’s engineers proposed an innovative approach
*Ben Coutts is director of engineering and research & development at Hydrasun
Aubin expands its expertise OFFSHORE CHEMICAL ENGINEERING specialist Aubin has launched a new integrity management and subsea division in response to demand from the oil and gas industry, the company said in a statement. The division will provide ground-breaking solutions to urgent challenges facing operators of aging offshore infrastructure both in the UKCS and internationally as well as permanent fixes. Aubin recently helped resolve one operator’s major integrity issue in the leg of a North Sea platform by adapting its patented L gel technology to create an internal pipework sealant on an asset in www.aubin.co.uk record time enabling repair intervention following a serious breach in integrity. It is also currently working with another operator to seal a breach in the external sheath of a riser in West Africa in an operation
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using a diver to apply its newly introduced sealant product AXIcast. In both cases, Aubin has devised solutions within days and, in the North Sea case, also secured regulatory approval. The new capabilities work alongside the company’s patented range of subsea chemical solutions, which have focussed on buoyancy as well as pipeline cleaning and repair. Aubin is advancing its line of integrity products, including AXI-cast, which can be utilised in subsea repairs, along with AXI-Lokk and AXI-gard, which are used for corrosion mitigation and plugging. The company is able to precondition pipelines to then utilise its gel solutions, saving additional time and cost to operators. Following use of the technology in the North Sea, an additional scope of work has followed.
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Magnum Technology Center, a wholly owned member of the WOM group of companies, designs and manufactures complete equipment packages for Well Testing & Production and Managed Pressure Drilling services for both onshore and offshore applications in skid or trailer mounted formats for the global oil & gas industry. We are meticulous about the little details that make our packaged solutions so seamless. Everything has been designed to work together perfectly whilst giving operators the flexibility to adapt. With a huge depth of hands on experience from across the globe our products are designed with the realities of real life usage in mind. Fully certified to industry and governmental standards and backed up by our extensive operational experience and customer support, MTC packages let you get on with the job in hand safe in the knowledge that we've done ours.
2000 Psi MAWP sample catcher in skid and crash frame
10,000 Psi / 1440 Psi / 50 Psi Self-contained Trailer mounted Well test package
For further details please contact: Mr. Brian Finnigan - General Manager | Mr. John Sajeev - Technical Sales Engineer E-mail: Sales@mtcltd.ae | Telephone: +971 4 816 3600
MTC Offices and Workshop facility in the Jebel Ali Free Zone, Dubai
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Technical Focus
Timberland PRO offers a variety of boots that meet specific on-the-job requirements for a broad range of industries, including oil and gas.
Footwear solutions for comfort,
durability and safety As Timberland PRO approaches its fifteenth year in business, senior product manager Xavier Kawula spoke to Oil Review Middle East about the company’s commitment to providing protective and durable footwear and its plans for expansion in the region.
U
S-BASED TIMBERLAND PRO is one of the leading competitors in the industrial footwear sector, creating premium products for markets that have specific on-the-job requirements. Established in 1999, the Timberland PRO brand was a product of The Timberland Company, who identified an opportunity to bring premium, durable work boots to industrial professionals. In September 2011, The Timberland Company was acquired by VF Corporation, a global work apparel and footwear company. “This merger has allowed Timberland PRO access to other like-minded brands and
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additional resources that will help us grow our product offering in the years to come,” Kawula said.
The company has so far worked with companies such as 3M, Ortholite, Vibram, and Agion to create unique footwear solutions
Tailor-made design
Timberland PRO offers a variety of boots that meet specific on-the-job requirements for a broad range of industries, namely oil and gas, construction, electrical, smelting and mining, among others. “All of our designs are crafted with the worker in mind to deliver the ultimate in footwear support,” Kawula said. The company says its highest priority is to stay closely connected to its customers in order to understand their everyday needs. “Our product and design teams at Timberland PRO continuously strive to identify what is relevant to our consumers now, what their needs are on the job site, and how environments or job tasks are evolving – all factors that influence product design,” Kawula said. “This allows us to offer superior value within products, while providing peak performance through best-in-class technical innovation,” he added. Examples of new technologies developed
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’
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Technical Focus
by Timberland PRO include the Anti-Fatigue Technology, which is incorporated into many of its footwear designs. Anti-Fatigue Technology utilises an inverted cone design that collapses and rebounds as the user walks, absorbing shock and returning energy back to the foot. “The lightweight design is specifically made for people who spend long hours on their feet to provide all-day standing comfort,” Kawula explained. The company has so far worked with companies such as 3M, Ortholite, Vibram, and Agion to create unique footwear solutions. “By collaborating with brands such as these, we are able to provide our consumer with product that exceeds expectations and performs to the maximum level,” Kawula said.
New horizons
“Timberland PRO is excited to expand our footwear offerings to the MENA region by providing inventory directly to both distributors and end-users,” Kawula commented. In 2013, the company became a priority footwear supplier to aluminium producer
Alcoa, including supplying its products to an aluminium facility in Ras Al Khair, a joint venture between Alcoa and Saudi Arabian Mining Company (Ma’aden). Under the contract, workers affiliated with Alcoa and Ma’aden now have access to Timberland PRO footwear designs for the oil
All of our designs are crafted with the worker in mind to deliver the ultimate in footwear support Xavier Kawula, senior product manager, Timberland PRO and gas and smelting industries. Kawula added, “We hope to create relationships with new distributors in the near future, which will give workers more access to our footwear in the region.” The company’s main focus in the MENA region is provision for the oil and gas industry, with slip-resistance technology and breathable styles suitable for the extreme heat.
“In addition, the boots feature electrical hazard protection, waterproof leather to keep feet dry, Ever-Guard leather for abrasion-resistance, Anti-Fatigue Technology for standing support and an ergonomic safety toe,” Kawula said. “They also feature either a finger grip pull on or side zip for easy on and off access,” he added.
Future collaboration
As a result of The Timberland Company’s acquisition by VF Corporation, Timberland PRO is set to develop closer ties with Bulwark FR, another brand owned by VF which produces fire-resistant work wear for the oil and gas, electrical and manufacturing industries. Kawula explained, “We will come together at global tradeshows and regional events later this year, to showcase our product alignment and ability to deliver a head-to-toe solution for the oil and gas industry. “Through this collaboration, we seek to offer both footwear and apparel that meet safety standards and deliver the durability needed to combat demanding work conditions,” he concluded. ■
VIKING expands global safety solution with onboard training DENMARK-BASED VIKING LIFESAVING Equipment has acquired a major stake in IT start-up SAATSEA, who offer cloud-based onboard training and competence management systems. SAATSEA, now renamed as VIKING Saatsea, said it addresses the need of ship-owners and operators to continuously train their crew by offering a combined solution that manages planning and implementation of onboard training as well as the documentation. VIKING CEO Henrik Uhd Christensen said, “We’re always on the lookout for anything that can make doing business easier for our customers while improving safety onboard the vessels. This addition to the VIKING portfolio has the potential to positively influence customer financials as well as safety.” Kim Baarsøe and Henrik Uhd Christensen (l-r) Through the online training system, the crew can complete and register modulebecome part of a broader solution. And VIKING has always based theoretical and practical assignments, with immediate, upstood out for us as a global company that has the worldwide to-date competency assessments for marine and offshore inspections – without administrative hassles, VIKING Saatsea said. reach we could leverage, as well as an end-to-end quality approach right across the value chain. Matching our solution to Kim Baarsøe, director of VIKING Saatsea added, “First and that level of quality at every stage of its delivery is, I believe, foremost, we are a team of solution developers. To take things crucial to our ability to succeed.” further, we needed the help of a partner where we could 154
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Technical Focus
Redefining pipeline
coating performance The field of oil pipeline coating has been revolutionised by visco-elastic coatings, which are an easily applied, environmentally sound and highly flexible solution to pipeline corrosion and sealing. Gurinder Singh Sethi, business director of India and sales for South East Asia at SFL, and Stopaq BV's Dr JF Doddema and Dr D.Cudic provide their expert insight into this versatile technology.
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IPELINES IN THE oil and gas industries represent a huge investment and have to operate safely and continuously for their design life. The basic property of strong adhesion is vital when considering external pipeline coatings. For underground applications like oil, gas and water pipelines resistance to cathodic disbondment (where the formation of hydrogen ions leads to the disbondment of protective coatings) is also vitally important. The majority of conventional coatings are not energy efficient and are cumbersome difficult to apply. The success or performance of a coating is highly dependent on the conditions when applied and the applicator’s skill level. Coating systems should protect the pipeline from external corrosion and coating degradation can lead to the creation of serious corrosion risks. Increased safety and integrity considerations mean that the demand for reliable, failure proof coating systems is high and increasing. Comprehensive research and application studies have led to the development of a coating system that can be applied with minimum surface preparation and also has a long life, even under harsh conditions; Viscoelastic (VE) coating is a non-polar, noncrosslinkable, non-curing and fluid-like polymer. It has a glass transition temperature that is lower than -65°C and a very low surface tension, exhibiting viscoelastic behaviour. VE coating is primarily made from polyisobutylene (PIB) with processing and blending. It is impervious to moisture and gases, meaning corrosion cannot occur beneath the surface. Fully amorphous, it forms no crystalline regions, in contrast to PE or PP or liquid/powder multi-component coatings. Therefore, no physical ageing or stress generation occurs due to postcrystallisation in conventional coatings. 156
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The composition itself does not show coldflow but the coating's composition means that coldflow is under control at temperatures of up to 150°C. On a molecular level the material wets steel and other pipe coatings and can even heal some defects and damage. Furthermore, as the inherent coating remains visco-elastic even below zero Celsius, any breach in the mechanical top layer causes the inner layer to flow out and 'self-heal' the top layer therefore eliminating maintenance concerns. The coating forms a monolithic coating within seconds as it flows into itself, thereby not allowing 'tenting' or spiral corrosion to occur which has been an industry issue for when using traditional wrap, liquid, powder and sleeve coatings. The benefits VE coating provides include: • Green technology - no emissions • Cold adhesion – self-healing at -45°C • Energy free and time saving application • No special application tools required • Unlimited shelf-life; no special storage • No cathodic disbondment; self-sealing • Cold application possible • Minimum surface preparation required • Underwater application • Does not require curing time • No under creep, no risk of osmosis • Stays flexible, does not crack or tear • Can be applied while pipeline in service • Meets ISO/Shell and TUV requirements • Product performance warranty The new visco-elastic polymer technology exhibits physical properties that meet the properties of conventional coating systems. On top of that the new coating material has some new additional 'life saving' properties inherent to the coating material like selfhealing (or rehabilitation) of small damages due to its viscous nature and no cathodic disbondment. Pipe coatings are also vulnerable to ageing caused by factors such as fluctuations
in operational temperature, mechanical stress and vibration, and exposure to varying ambient conditions. It is known that the adhesion properties of several types of coating deteriorate significantly after hot water immersion testing. After exposure for 100 days, the peel test result was the same as the un-aged sample. Visco-elastic material is therefore an anti-aging corrosion prevention system. Anti-corrosion coating failures are a significant factor in the reduced operational life of pipelines and can result in leaks requiring repair, clean up and in some cases the replacement of the pipeline. The costs of repair and replacement are significant, as are costs associated with spill containment and clean ups. The cost, environmental impact and negative publicity associated with failures are something every major oil and gas company seeks to avoid. Traditional coating systems exhibit high failure rates, resulting in either major repair works or the replacement of expensive distribution systems, while the chemical and physical properties of visco-elastic coating material do not cause such degradation problems. The visco-elastic coating technology has been designed and tested to fit the field application and performance requirements of oil, gas and water pipelines. The total VE coating system (coating material + mechanical protection) can be tailored to meet the specific impact, shear and temperature requirements of the end-user. VE coating technology is now being widely used as a factory applied coating, for pipeline coating rehabilitation and as for field joint projects worldwide and is widely specified by many major oil and gas companies. Viscoelastic coatings are emerging as a versatile and cost-efficient solution to corrosion prevention and sealing. ■
For more information, please go to www.stopaq.com
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Technology
Expro Meters' clamp-on meters provide nonintrusive flow measurement solutions for clients
Delivering effective
metering solutions International oilfield services company Expro has seen a significant increase in demand for its metering technology in the Middle East and North Africa, with a successful project delivered in Iraq and anticipated growth across the region this year.
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XPRO METERS OFFERS on-demand, cost-effective, nonintrusive flow meters and measurement services for individual well, flowline and overall field production surveillance. These solutions enable customers to realise increased value from their wells and fields through improved production monitoring, optimisation of well performance, increased efficiency and reduced metering costs – all with reduced health, safety and environmental exposure. Through its use of innovative SONAR technology, Expro Meters provides full solutions to clients’ wellhead surveillance needs - from research, engineering and manufacturing through to field delivery – and the company continues to undertake a growing number of meters based projects in the Middle East.
Measurements
SONAR is a metering category which was first introduced to the oil and gas industry with the deployment of the first downhole, fibre optic multiphase flow meter in 2000. The SONARMonitor™ concept provides a 24/7 service to customers, providing non-intrusive flow measurement solutions for onshore and offshore wells and downstream applications, including pipeline monitoring. The SONARTest™ service is based around a well 158
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testing and flow measurement service which is applicable for single and multi-phase conditions, where one engineer armed with a meter can provide accurate flow measurements in a single day. SONARTest is well suited for customers who desire ‘snap-shot’ measurements for individual well production and downstream pipeline measurements. Multiphase Solution - Expro Meters has developed the SONARbased Total Production Surveillance (TPS) system for flow measurement of black oil and gas condensate production wells. It utilises SONAR clamp-on flow metering technology and leverages a combination of PVT models and multiphase flow correlations. The SONAR meter measures the bulk flow velocity and the TPS system then determines real-time inferred rates of the associated phases using the pre-programmed wellbore composition and EOS model and pressure and temperature inputs. For situations where the wellbore composition can be reasonably estimated, SONAR TPS produces results that are comparable to traditional in-line multiphase meters.
Our solutions are delivered in a comparatively small package and are ideally suited for offshore installations Important role
Monitoring produced gas, oil/condensate and water rates from individual wells plays an important role in reservoir management and production optimisation. Obtaining timely and accurate wellhead measurements can be challenging due to a range of factors. Conventional (gravity-based) well test separators are costly and can at best provide periodic
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measurements. In-line multiphase flow meters can be expensive, rely on nuclear sources and, due to their intrusive nature, can result in deferred production to accomplish a well test. The small footprint clamp-on wellhead monitoring package is highly mobile and easily installed on existing production pipework.
Commonplace
These factors make it an ideal solution for challenges that exist in the Middle East and North Africa where remote desert based wellheads are commonplace. In conditions where is it challenging to perform traditional well test at the required regularity Expro Meters solution is can deployed to rig up and test the well in a single day with no deferred production or leak paths providing a well test report to the client within three working days. Patrick Curry, general manager of Expro Meters, said: “Our successful client engagements have a common theme: the customer desires more data on their individual well production or pipeline flow rates, but they do not have the capital budget to retrofit the field or pipeline network with traditional in-line flow measurement devices and they can’t afford to shut-down production while that work takes place. Our products and services, which are
all clamp-on, give our customers the flow data they need at a reasonable cost and can be rapidly deployed, avoiding lengthy construction projects.
Accuracy
“Our solutions are delivered in a comparatively small package and are ideally suited for offshore installations, unmanned platforms and remote land locations. In addition, all of our customers are focused on reducing HSE risks, and clamp-on technology offers obvious significant advantages in this area. We do all this without compromising accuracy.” With more than 600 jobs completed for clients around the world, including many of the leading IOCs and NOCs, Expro Meters already has an established reputation for delivering the data. Its track record has seen successful deployment in a wide range of applications, with jobs completed on pipes ranging from 2”to 30” and pressure ratings ranging from 15psi to 8,000psi. Towards the end of 2012, Eni Iraq commissioned Expro to provide SONAR meters for production testing on a number of oil wells in the Zubair field in southern Iraq, which Eni Iraq B.V. operates with the country’s state-owned South Oil Company.
Testing
These factors make it an ideal solution for challenges that exist in the Middle East
Expro Meters solutions are delivered with a very small footprint
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SONAR surveillance technology was deployed to monitor produced oil, gas and water rates from almost all of the wells in the field, including ESP lifted (electrical submersible pump) wells, under extremely challenging environmental conditions including 50 degree C heat, and a subsequent successful evaluation of the
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project by Eni Iraq led to an extension of the contract to continue the programme of testing. However, the success of the project has extended well beyond well monitoring. Expro Meters has developed a training and development programme for Iraqi nationals, and field activities are now being run by local engineers who are performing operations with the highest levels of commitment. Ahmed Hussien, Expro Meters’ Iraq service coordinator, said: “Successful implementation of the programme, along with Expro’s Iraqi nationalisation plan, has made Expro Meters the service provider of choice, and the team has achieved a meaningful contribution to Zfod and Zubair field production optimisation.” The success of the project has generated considerable interest, and other major companies in the Middle East have requested SONAR monitoring for evaluation. Curry concluded: “Our relationships with clients in Iraq are textbook examples of how we can add value to our clients’ operations. Working at the business development stage to develop the application with the customer, providing expert technicians at the well site, producing accurate data quickly and identifying and training local employees to assume responsibility for well site operations lead to customer confidence in us and our products.
Expro Meters’ ActiveSONAR meter in operation “We have a truly game-changing technology that has been tailored to the oil and gas industry. In a relatively short time, we have built a robust track record of success stories with many leading IOCs and NOCs. We’re proud of the value we are bringing to our customers.” ■
Innovation runs deep
Leak detection module
WITH AN IMMENSE range of innovative solutions designed to protect and extend the life of critical assets, protect people and the environment in which they operate and improve productivity. 3M Oil & Gas offers a wide variety of ingenious oil and gas industry product solutions.
REAL-TIME ASSET INTELLIGENCE company OptaSense announced the addition of its four-mode leak detection module to its industry leading Pipeline Integrity Management platform. The new software based enhancement module brings together four methods of leak detection – negative pressure wave monitoring for rupture events; acoustic signature recognition of high pressure leaks; fast Distributed Temperature Gradient Sensing (DTGS); and ground heave strain monitoring – into a single platform, providing a comprehensive leak detection system. This new leak detection module www.optasense.com greatly enhances the business case for using fibre. Optasense technology enables customers to obtain an unrivalled level of data from a single system. For the first time a single system can deliver the full suite of pipeline integrity management requirements including third party intrusion and leak detection as well as operational condition monitoring eg pig tracking. The module combines all of the four most commonly used detection methods, making the system significantly more sensitive and able to provide more accurate localisation than alternatives such as Flow Mass Balance and Chemical Sensing. The module allows for leaks to be detected and repaired more efficiently than in the past, improving safety and potentially reducing financial losses resulting from the leak. The OptaSense Pipeline Integrity Management platform uses standard fibre optic communications cables as sensors to gather data on potential leaks.
www.3Mgulf.com
More than 60 years ago, 3M earned its place in an oil and gas application for the first time. Today, nearly 10,000 of the company’s products and materials are used in every corner of the industry – from exploration, production and refining to transportation and marketing. The 3M Oil & Gas Group believes it can provide proven, practical and ingenious products that can be put to work right now to help make workplaces safer, more productive and efficient. From maturing oil or gas reservoirs or drilling in deeper waters, to meeting ever-increasing safety and environmental regulations, 3M says its range of practical and ingenious solutions can help you meet your toughest challenges.
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Technology There is increased demand for temporary high-end offshore accomodation solutions, says HB Rentals.
Raising the bar in offshore
accommodation
HB Rentals says it offers a fully-integrated service
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HERE’S A GROWING demand for higher specifications in the temporary offshore accommodation sector in the energy industry. The end user wants the best and the service providers are changing the way they operate to meet customer needs. Companies have more recently identified that providing comfortable, functional and most importantly safe modular units for offshore workers has a direct impact on productivity. As a result the latest in cutting edge design and safety standards is now on offer in the market. That allows oil company employees to experience a near home from home environment whilst working in challenging and demanding locations. 162
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Turnkey solutions
If an accommodation provider can offer such a comprehensive service this eases the demands on the hiring companies and allows them to concentrate on their core day-to-day activities. That’s where a renowned niche market specialist like HB Rentals comes into its own as it offers all the tools of the trade in terms of a fully integrated service.
Since the expansion into the Gulf it has quadrupled the size of its fleet
The company has been offering such turnkey solutions in terms of accommodation, engineering, design, installation, hook–up and commissioning services to its clients since the 1970s. Originally its target was the North Sea and Gulf of Mexico but the company now has a global reach. HB Rentals says it has a reputation and history across the world for taking on every aspect of the job from beginning to end. But just what sort of new trends has HB Rentals noticed in the sector, specific to the Gulf Region, during 2013? Rami Miled, HB Rentals Business Development Manager for Middle East and North Africa, picks up the discussion as he looks ahead with confidence following a market revival.
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“There’s no doubt our clients want to see progressively higher specifications when it comes to the end product,” he said. “That approach is common right across the industry particularly as oil prices have been rising from as early as January this year. “Health and safety standards in the GCC promote comfortable living quarters for those working on remote offshore locations. “Everyone now has access to his or her own television along with a dedicated Internet connection – it is almost like living in a hotel. “There’s real confidence in the market and that can only be good news for HB Rentals in the short, medium and long term as we set about further establishing the brand into new regions.”
Challenge
But just what sets HB Rentals apart from its rivals in what has quickly become a competitive market? Miled added: “We take real pride in our units for many different reasons. In particular they use less deck space than our competitors, are lighter and we can fit in more beds per square metre. “These are all attributes that our clients look for and value in their accommodation provider.
“We as a company at HB Rentals are more than happy to liaise directly with the client, invest time and money into the project, to meet their expectations. “But with that there’s also a real challenge there too as we’re facing different demands for diversified products especially when it comes to turnkey facilities. “Oil companies are eager to create social spaces for their employees so they can enjoy some downtime when they are off shift. “However, HB Rentals is ideally placed to provide the total package when it comes to finding market solutions for all types of different requests we receive.” After a fruitful 2012 HB Rentals is gearing for further development and expansion with a specific focus on the Middle East. Since the expansion into the Gulf it has quadrupled the size of its fleet and expects greater growth during this year.
Demand
The future business drive is based on fundamental practices that have served the company well for more than 30 years. It is also continuing to develop its reach within the Middle East region since opening in Dubai in October 2010.
Miled added: “As an established company we have a strong presence globally, with fresh emphasis on the Middle East, which places us in an enviable position. “However, like everyone else we face regular challenges. There is competition from international and local companies and that is increasing. “That is why we’re always continually educating clients on new products whilst continuing on our own organic growth and market penetration strategies. “We are well aware business is about developing long-term relationships and showing we’re flexible, innovative and most importantly customer focused.” There is currently considerable demand in the Middle East the opportunities for increased market share for HB Rentals grow simultaneously which in turn should see the modular accommodation provider develop even quicker in the region. The company recently introduced its Elite Series, a unique, in-house manufactured wheel-mounted accommodation fleet for the onshore market. This new design combines customer feedback with modern engineering to produce a higher-quality, better-constructed and more comfortable living solution. ■
Amarinth lands further orders for Zubair Initial Production Facility in Iraq AMARINTH, A LEADING company specialising in the design, application and manufacture of centrifugal pumps and associated equipment to the oil and gas, petrochemical, chemical and industrial markets, has secured a new order in Iraq to supply a further eight API 610 OH2 A-Series pumps to the Zubair Initial Production Facility. Last year, working with its agent in the region Horizon Development International, Amarinth secured its first business in Iraq to provide twelve API 610 11th edition Super Duplex OH2 A-Series pumps in Super Duplex for the produced water treatment package for the Zubair Initial Production Facility located in Basra in southern Iraq. Following the successful delivery of those pumps on a short 24week delivery, US giant oil services company Weatherford International, which holds the oil field facilities contract for Iraq's Zubair oilfield, placed a further order for eight pumps to the same specification, on the same 24week delivery. This brings the total order value of pumps supplied by Amarinth to the Zubair Initial Production Facility to over US$1.5mn. Amarinth are also in on-going discussions with www.amarinth.com Weatherford International to
supply more pumps to the same project. Iraq is proving to be a rapidly expanding market for suppliers to the oil and gas industry and Amarinth has been building quickly on its initial successes. The company has received approved vendor status from both Lukoil (Russia's second largest oil company) and ENI and is progressing opportunities in the region with Iraq’s state owned oil companies South Oil Company and Midland Oil Company. Oliver Brigginshaw, Managing Director of Amarinth, added, “We are delighted to have secured this further order in Iraq with the help of our agent Horizon Development International. Whilst Iraq still poses many significant challenges, having a good local agent such as Horizon Development International is essential for trading in the country. We are currently seeing further significant growth opportunities in the region and the work we have completed to date to establish a foothold in the market, and these new reference sites coming online within Iraq within the next 12 months, will leave us in a strong position to win further business in the region.” Issue 7 2013
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Innovations
New pipeline clamp installation tool launched T.D. WILLIAMSON (TDW) has announced the introduction of its new Clamp Installation Tool (CIT). The new remote-controlled system makes it possible to install any proprietary clamps or fittings on subsea pipelines in need of repair or to prepare for tie-ins to new pipelines. The lightweight CIT is operated via remote control through a laptop by an experienced technician onboard a platform or a diving support vessel (DSV). As a result, operational safety is enhanced, and control over clamp installation operations is greatly improved. The development of the CIT follows the release of TDW's remote-controlled Subsea 1200RC Tapping Machine in 2012. This offered a diverless solution to subsea hot tapping in depths of up to 3,000 m. Subsea hot tapping is necessary to facilitate tie-ins, pipeline repair, and flow assurance. Up to 98 per cent of subsea hot tap operations involve the use of a post-installed mechanical tee with elastomeric pressure sealing elements, while only TDW’s Clamp Installation Tool two per cent use hyperbaricwelded tees or pre-installed tees, due to the expense. To offer pipeline operators a costeffective way to remotely install mechanical tees prior to the hot tap or as part of an integrated hot tap assembly, TDW developed the CIT. The CIT is small, lightweight and easy to deploy. As with the Subsea 1200RC Tapping Machine, it is a topside-driven tool with a passive remotely-operated vehicle (ROV) interface. The installation package consists of four basic units: a control skid, ROV, clamp or fitting, and the installation tool. "With the introduction of this versatile, remote-controlled Clamp Installation Tool, our efforts to separate man from machine during the clamping and subsea hot tapping process are now a reality," said Mike Benjamin, senior vice president – marketing and Technology for TDW. "By doing so, we offer a solution that dramatically reduces risks to personnel and increases efficiency. Looking ahead, we are confident that it will soon become the industry standard for all subsea clamping and hot tapping operations, whether they are carried out to pave the way for repair work, tie-ins or chemical injection."
Frames and Paqell sign desulphurisation licensing deal PAQELL AND FRAMES Gas Processing have entered into a licensing agreement for THIOPAQ O&G's desulphurisation technology. The agreement adds THIOPAQ O&G technology to Frames’ gas treating portfolio, enabling Frames to offer sulphur recovery technology to their customers and therefore provide complete sour gas solutions. THIOPAQ O&G technology offers an environmentally friendly way to remove hydrogen sulphide from high or low pressure natural gas streams or associated gas streams and convert it into elemental sulphur. LNG production at Shell’s Qatargas 4 The system is cost-effective, uses low energy and requires minimal effort to operate. “The simplicity and effectiveness of the THIOPAQ O&G technology aligns with Frames’ core business philosophy of designing and building technologically advanced high quality process and control systems,” said Chris Klukkert, business unit manager for Frames Gas Processing. Paqell managing director, Joost Timmerman, added, “As Paqell’s technology is seeing a breakthrough at the beginning of 2013, we sought a new international partner who is able to not only design but also construct THIOPAQ O&G plants. Frames’ ability to build complete integrated solutions with a focus on sustainability adds value and brings more flexibility in the offering to our clients.” Paqell is a joint venture between Shell Global Solutions International and Paques which was established in 2011 to focus on the marketing of biological desulphurisation in the oil and gas sector for gas applications. Frames is an international provider of innovative process and control systems to the international upstream oil and gas industry. 164
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Advanced pipeline protection USING ITS INNOVATIVE and durable products, Borouge provides pipe solutions for water and sanitation, gas distribution, industrial applications and domestic heating and cooling systems. A joint venture between Abu Dhabi National Oil Company (ADNOC) and Austrian chemicals and plastics specialist Borealis, Borouge's products include the Borcoat™ steel pipe coating system. Borcoat™ polyolefin solutions provide steel pipes long-term protection against a range of elements including corrosion and abrasion, mechanical impacts, chemicals within and outside the pipe, UV radiation, thermal stresses - high and low temperatures and environmental stresses. Borcoat™ 3LPE coating systems consist of a Bimodal high density polyethylene (HDPE) top coat and grafted copolymer adhesive which brings far greater efficiency to coating production, application and maintenance than conventional polyethylene systems. With the new high performance HDPE top coat, Borcoat 3LPE system is suitable for a wide design temperatures range (-45° to 90°C). For onshore pipelines requiring a higher design temperatures of up to 110°C, Borouge offers a Borcoat™ three layer polypropylene (3LPP) coating system with a PP top coat. This provides excellent thermal ageing resistance and UV protection together with a high-temperature compatible Borcoat™ PP grafted adhesive. For challenging deep sea, high temperature offshore pipeline projects, Borealis offers a family of Borcoat™ polypropylene (PP) thermal insulation coating materials for multi-component (4LPP, 5LPP or 7LPP) systems covering a design temperature window of -20°C to 140°C. Borcoat™ PP foam insulation grades exhibit high compressive strength necessary to resist the pressures of deep-water installations. However good the mainline coating is, unless the field joint coating is also reliable, which is carried out in the field after the pipes are welded in series, it is not possible to guarantee the service life of the pipeline. New Borealis innovation, the Wehocoat–Borcoat field joint coating system, brings the protection of welded joint coating up to the same quality level of factory applied mainline coating, thereby making an end-to-end solution possible.
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Innovations
Van Beest introduces fixed nut shackles SHACKLES ARE NOT just used for lifting applications but for more permanent constructions. These can be subject to dynamic loads and/or extreme vibrations. In such applications there is a risk over time that the nut starts moving over the thread. To overcome this risk, Van Beest has introduced its range of Green Pin® Fixed Nut Shackles that have many potential uses in the oil and gas, mining, shipping and fishing industries. Green Pin® Standard, Polar and Super shackles can be equipped with a feature that consists of an extra AISI 316 securing bolt which is drilled through the nut and shackle pin. This securing bolt is fastened with two sets of Nord-Lock® washers and a securing nut. This will keep the shackle nut in position. The Nord-Lock wedge-locking washers lock when subjected to extreme vibration or dynamic loads. Green Pin® Fixed Nut Shackles are available on request only.
For more information go to www.vanbeest.com.
Pipex heads to SAOGE TUBE SPECIALIST PIPEX Italia is set to exhibit its products at the upcoming fifth Saudi Arabia International Oil & Gas Exhibition (SAOGE), which takes place from 25 to 27 November at Dhahran International Exhibitions Centre in Dammam. Pipex Italia is the sales and distribution channel of Železiarne Podbrezová Group, a leading manufacturer and supplier of steel tubes, tube semi-products and tubular fittings. The company is set to take to Stand 422 at the exhibition in Saudi Arabia. The company specialises in manufacturing hot rolled steel seamless tubes and precise cold drawn tubes from carbon and low alloy steel.
The tubes, which range in size from three to 140 mm, are designed for use in various fields of industry, in particular in the energy, engineering and automobile production sectors. With a consolidated turnover of US$743mn, the Železiarne Podbrezová group employs more than 6,000 people in Slovakia, the Czech Republic, Spain, Italy, Poland and Germany. The company is ARAMCO and KNPC approved . Pipex Italia's appearance at SAOGE forms part of the company's ongoing efforts to further develop its presence and create opportunities within existing and new markets. www.pipex.it
UPS system solutions for offshore platforms AN UNINTERRUPTIBLE POWER supply (UPS) is mandatory on oil rigs. First and foremost this is because, for safety reasons, the signal lighting must be operational at all times. Complete blackouts or malfunctions in the mains power supply, such as frequency fluctuations or overvoltages caused by lightning strikes, must be safely bridged on oil rigs. Above all, functioning signal lights are not only essential for smooth operation on the rig, but also for the safety of all nearby ships and airplanes. Therefore, the position lights must not fail under any circumstances. The chargers for UPS batteries must be able to function in extreme heat when installed in the MENA region. R. STAHL provides UPS for hazardous areas which ensure the safe operation of systems that require 100 per cent availability. The company provides solutions for such environments, placing battery chargers in the largest of its available CUBEx enclosures and utilising several special features to ensure heat dissipation. 166
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These include a patented cold plate technology, a heat sink attached to the side of the enclosure and a stainless steel fan for hazardous areas with a motion monitoring function. Forced cooling is controlled and monitored by an intelligent control system. Explosion protection for Zone 1 is ensured by a special feature which is unique to R. STAHL UPS systems: an integrated UPS guard monitors the functions of the battery charger and the batteries, which are also installed within the zone. R. STAHL is able to implement very compact, weight-optimised systems within limited installation spaces on offshore platforms. All outside metal parts of the seawater-resistant CUBEx enclosures are made from SS316 stainless steel. This material requires no further surface treatment for use in maritime environments. R. STAHL offers adaptable UPS units that are assembled from a modular design kit and also provides a wide range of explosion-protected enclosures.
Brück sees demand from oil and gas market surge BRÜCK, A GLOBAL leader in forged and seamless hot-rolled rings, flanges, and special forgings, has seen an upsurge in demand for its products and solutions from the oil and gas industry. “The application areas for many of the industries to which we supply equipment have become increasingly critical in recent years, for example, higher temperatures, greater pressures and depths, and more corrosive atmospheres," said Jack Hoeben, manager of projects at Brück. "This is particularly true of the oil and gas, and certain branches of the power generation, industries we service. "This means that equipment, once installed, cannot always be easily replaced. It has to hold up under these arduous working conditions without respite. From experience we have become experts in tailoring equipment to meet customer requirements under these conditions, though we are naturally still learning as application difficulties continue to evolve." Brück is able to forge a virtually unlimited range of middle-to-large product dimensions in more than one thousand different grades of materials, ranging from carbon steels through stainless steels to nickel-based alloys, aluminium, and titanium. The company has specialist staff for each industry segment, meaning that project management personnel well versed in, for example, the oil and gas and power generation sectors. Orders for equipment that meets complex specifications has surged since the Deepwater Horizon incident in 2010, according to Brück's innovation and research and development manager, Raymond Cordewener. "In parallel we also see that sometimes customers may not exactly know what they need in terms of specifications or may even come to us with conflicting specifications without knowing this, or with specifications which may not adequately fit the job,” said Cordewener. Brück therefore ensures that it investigates exactly what is required and what the application of the product is, even with run-of-the mill orders. Brück opened its regional office in Dubai in 2010 and currently employs six members of staff to service the region.
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Innovations
Nitrogen generation systems in offshore E&P THE USE OF nitrogen in the offshore oil and gas industry plays an integral role in the day-to-day operations aboard mobile offshore drilling units, FPSOs, and drillships around the world. Many applications, such as the blanketing or inerting of storage tanks aboard FPSOs, or the charging of subsea blowout preventer (BOP) accumulators, revolve around safety. Others, like the drying of coiled tubing to prevent corrosion resulting from long-term moisture exposure, serve largely economic concerns. Without nitrogen, completing these tasks would come at increased operational risk and result in greater costs for operators. The sourcing of nitrogen for the current and next generation of offshore vessels can pose fundamental logistical challenges for operators. Many operators continue to transport fully pressurised bulk tank bundles or liquid nitrogen tanks from shore to ship. There are inherent safety risks in these transports and there are often realised losses in transit that prevent operators from fully utilising the gas that they have purchased. The effects of equalisation and pressure decay once the gas is aboard the vessel also need to be taken into account. This often causes unplanned downtime events and additional labour from operating crews having to continually disconnect and reconnect bottle valves and pipe connections. Having a dedicated nitrogen source aboard the vessel is a safe and efficient choice for vessel operators for many reasons: • It acts independently of large-scale rig or ship nitrogen systems, alleviating concerns about potential under-pressurisation or pressure decay. • The large-scale nitrogen system then becomes a backup system, adding redundancy to whatever process is being serviced. • It operates only when required by the process it is dedicated to; with the addition of optional downstream storage, the system will only operate to keep this storage volume fully pressurised, ensuring full gas supply pressure at any time it is required. Operators recognised the benefits of having a dedicating nitrogen generation system for BOP accumulator charging following the aftermath of the Deepwater Horizon disaster. Bauer Compressors provides a turnkey solution that meets current ABS and DNV certification standards and can operate continuously in all manner of environmental and hazardous conditions, all while
Bauer’s Series II Stationary Nitrogen Generation (SNG) system maintaining consistent pressures in the accumulator stacks. This has been integrated into nearly two dozen new drillship projects since 2010 and Bauer is also working with shipbuilders and designers to retrofit existing vessels as they are taken offline for repairs. The company is constantly striving to find new, innovative ways to improve onsite nitrogen delivery for mobile offshore drilling units, drillships, and production vessels. BOP accumulators are not the only application that can benefit from a dedicated nitrogen system. Tensioning systems, currently airdriven, are prime candidates for nitrogen conversion. Flooding tubing coils with sufficient volumes and pressures of nitrogen will help to save both time and cost resulting from corrosion damage, both offshore as well as onshore. BOPs will continue to operate at deeper depths and the need for dedicated nitrogen generation systems will only increase during the coming years.
Schlumberger introduces new sonic-while-drilling service “The SonicScope service is a key component of a real-time SCHLUMBERGER HAS RELEASED its new SonicScope multipole workflow aimed at drilling wells more safely by estimating pore sonic-while-drilling service for wells with large boreholes. The pressures in various geological SonicScope service provides layers and enable operators to high fidelity measurements to adjust mud weight windows determine formation pore accordingly.” pressure and breakout limits to To increase operator confidence in improve drilling risk sonic measurements and improve management. decision making, a comprehensive "When drilling in challenging quality control process - consisting environments such as of a series of unique control plots deepwater, operators are often is applied to confirm the data is faced with mud weight selection unaffected by external factors. The and wellbore instability issues SonicScope service also features a that can be a result of fast-logging multimode capability uncertainties of pore pressures that enables top of cement in geological layers,” said Steve identification with consistency and Kaufmann, president, drilling and Schlumberger's SonicScope service provides high fidelity measurments repeatability while tripping. measurements, Schlumberger.
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CompAir launches new oil-free range COMPAIR HAS LAUNCHED a brand new range of two-stage oil-free, rotary screw compressors. The new D-Series further enhances and complements the oil-free compressor technology expert's recently updated water injected DH models. The 75 to 160kW air cooled range, with flow rates between 8.88 and 23.56 cu m per minute, offers air purity that meets the most stringent standards and has been certified ISO 8573-1 Class Zero (2010) and silicone free. The two-stage CompAir D-Series delivers reliability for demanding applications, state-ofthe-art performance and in-depth control from its multilingual Delcos XL controller. By continuously monitoring operational parameters the controller protects the equipment, while CompAir's own designed and developed airend lowers lifecycle costs by working at constant low temperature levels. CompAir's use of modern inverter technology for the regulated speed models, maximises energy savings with up to 25 per cent achievable over a comparable fixed speed unit. The high output, two stage airend design provides 100 per cent oil-free and near isothermal compression with high Compair’s D132 reliability thanks to constant low temperatures, allowing use in demanding applications in up to 45°C ambient temperatures. The highly efficient WEG IE3 electric motor offers high reliability and operational safety and features automated motor lubrication. The compressors utilise two efficient radial fans, offering low noise levels, low pressure loss and excellent cooling performance. The closed water circuit for airend cooling achieves a constant low temperature level, meaning that less gearboxes are required. CompAir's systems also utilise the latest energy efficient technology. The compressors have a small footprint of just 4.5 sq m, are easy to install and service and feature a low number of parts. All units have a 8,000 hour standard service interval and are covered by CompAir's comprehensive and free, 'Assure' warranty programme. This cover lasts for up to 44,000 hours or six years, whichever comes soonest.
LUX Assure completes first major regional contract LUX ASSURE HAS announced the completion of its first major work in the Middle East using its innovative corrosion management tool, CoMic™. The Scotland-based oil and gas chemical monitoring firm secured a contract with Kuwait Oil Company (KOC) research and technology division in Ahmadi to provide support for a sea water pipeline in North Kuwait. The scope of work involved LUX Assure’s senior scientist, Cameron Mackenzie, working onsite for several days using CoMic™, one of the company’s core oil and gas technologies, to evaluate the functional dosage of a corrosion inhibitor being applied in a transportation pipeline.
LUX Assure senior scientist Cameron Mackenzie
Dynagas chooses sustainable marine solution from GE GREEK SHIPPING COMPANY Dynagas has demonstrated its commitment to supporting clean technologies by investing in two new LNG carriers featuring energy-efficient power and propulsion systems constructed by GE's power conversion division. "Dynagas recognises its responsibilities to the industry to deliver its service in a safe, reliable and economically competitive manner," said Manos M. Migadis, new building project team manager at Dynagas. "The goal of the company, the LNG shipping arm of the George Prokopiou group, is to grow in size and reputation and expand its ability to serve the industry." The two new dual-fuel-powered LNG carriers - the Arctic Aurora and the Yenisei River were handed over recently to Dynagas by Hyundai Heavy Industries (HHI). Dynagas will also take delivery of five other LNG carriers over the next two years, all equipped with GE's innovative, energy-efficient, variable168
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speed electrical power and propulsion systems. "Dynagas has a strong commitment to reliable, well-proven and energy-efficient propulsion systems," said Paul English, marine business leader at GE Power Conversion. "Earlier vessels have been equipped with steam propulsion, so we are very happy that HHI, which is a long-term customer of GE and a strong advocate of our induction motor-based systems, has convinced Dynagas of the merit of our technology." For each vessel, GE will supply a fully integrated power and propulsion package that includes a MV7000-series induction motor, alternator, converter, transformers and switchboard. Each package is fully tested on a real-time simulator (RTS) that creates conditions at sea at GE Power Conversion’s Power and Control Integration System Centre of Excellence (PCIS COE) in France, before
The dual-fuelpowered Yenisei River LNG carrier being shipped for installation by HHI at its shipyard in Ulsan, Korea. GE’s MV7000 drive technology delivers efficient and flexible control of electric power, which is around 30 per cent more efficient than steam-based mechanical power and is now used across a broad range of applications and industries. The fully integrated package is backed up by a global team of technical experts.
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BP needed high-speed connections between its various offices in congested Cairo.
From the wellhead to
the rooftop
When BP in Cairo decided it needed reliable high-speed connections between its various offices, it chose a wireless technology that may be unfamiliar to some readers. However, use of free space optics is growing as part of the need for even more alternatives to traditional wired and wireless communications, as Vaughan O’Grady finds out.
“W
E REALISED PEOPLE would be reliant on these things - that downtime would be abhorrent. So we had to do three things. One was design a product that was the most reliable possible and wouldn’t fail. Second to only sell it in environments to which it was suited. And lastly to make sure it’s backed by resellers who can provide any service the customer needs.” We are talking here about communications. Or, more accurately, Stephen Patrick is. Patrick is the CEO of Wireless Excellence Limited, a leading designer and manufacturer of professional wireless products for a wide variety of applications. That includes Wi-Fi, WiMAX, microwave, millimetre wave and more. ‘More’, in this case, includes free space optics (FSO), which uses infra-red laser technology to transmit data. The focus on FSO in this article is because BP in Egypt has chosen what may, to many readers, be an unfamiliar wireless technology to send data to and from its various Cairo offices. As for why it chose the technology, the
background is as follows. BP has had a presence in Cairo for a long time. It was consolidating facilities into different offices or buildings around the city. It therefore required high-speed links between those sites, a not unusual need where multiple buildings in the same city are involved. Patrick takes up the story: “BP realised that relying on the local telecom provider was going to be not only very expensive, but would not enable them to reach their desired availability and reliability targets for the network.
Consistent
Conversely, ‘owning the infrastructure’ with a wireless solution means that all the equipment is owned and under control of the
Equally important, FSO is not affected by rain, which can be a problem for a number of technologies
customer - who can therefore take whatever actions are required to ensure consistent and high uptimes. A local partner responded to an enquiry made by BP locally in Egypt, and suggested our solution as the ‘best fit’ for the customer needs.” Wireless Excellence offers a number of different wireless systems but in this case Patrick is referring to FSO. In principle, the idea is simple: you have a box that generates a laser beam - a very low power light beam - which is modulated. It carries data in the form of ones and zeros from one point to another point. There they are converted back to data. In practice, however, making this technology reliable has, Patrick says, cost the telecommunications industry as a whole many millions of dollars and a lot of work. Even when it was commercialised back in the late 1990s companies like Wireless Excellence had to overcome a lack of awareness of FSO (compared to, say, microwave or fibre) with demonstrations and trials. But it has been worth it, and not just for Wireless Excellence. Customers especially Issue 7 2013
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like the fact that point-to-point wireless communication using laser is, in most countries, licence-free. In addition, radio spectrum is a limited resource; the microwave spectrum tends to be congested in major cities with hundreds, or even thousands of links all competing for the same frequencies. Infra red, however, is uncongested.
Increasing congestion
FSO’s other advantages include quick set-up, very high speed (1 Gbps) and low annual fees to Egypt’s NTRA (National Telecom Regulatory Authority) compared with other wireless technologies. In fact, Patrick explains, “With our reseller we have worked with the NTRA to ensure that all the products and installations meet their needs. The fact that these products use optical (infra-red) rather than RF spectrum means that they are very supportive; these products don't add to the severe and increasing congestion of RF bands, so there is a motivation for all parties to choose optical links where appropriate.” FSO does have its limitations. Transmission is only up to two kilometres as a rule (though much longer links have been achieved: up to four km or more) and it requires line of sight transmission. That means, in cities most of all, the transmission and reception equipment is usually rooftop-based. Careful planning is therefore required to ensure that the desired links can be implemented. Also in some cities and regions of outstanding heritage the user may also be at the mercy of planning regulations. However, most business users, including BP, are fortunate in occupying fairly tall buildings where line of sight is easy to attain, and the units are usually not visible from street level. If a company using FSO doesn't own a building it can usually negotiate with building owners for rooftop access. 172
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Deterrent
Sometimes more height is needed to ensure line of sight. In such cases small masts can go on top of buildings. In some situations there may even be what Patrick calls “a snooker shot”: pointing a beam at a laser ‘box’ on a different building where a repeater installation redirects it to the one you need to link. The owner of the extra building usually exacts a modest rental for the favour but that is rarely a deterrent to the client. What about Cairo? As Patrick says, “It's a busy city! All our wireless links are up on rooftop level, and mounted in locations where there is clear line of sight between locations. Our skilled resellers are expert at finding suitable points, starting with maps and then checking by visiting the rooftop sites themselves. It's actually a lot easier than it sounds - and to put it in context globally for the whole industry, there are upwards of a million wireless links a year being installed on similar rooftop sites.”
In practice, however, making this technology reliable has, Patrick says, cost the telecommunications industry as a whole many millions of dollars and a lot of work Nevertheless other factors can be a problem. For example FSO is also limited by the weather - things like thick fog, heavy snow and in certain conditions extremely heavy sandstorms, although that still makes it viable for much of the Middle East and
Africa. As Patrick points out, “This deployment is typical of ones we have done in 65 countries globally. The customer needs, and the solution itself, are as valid and attractive in Cairo as they are in cities as diverse as London, New York, Cape Town, Riyadh, Dubai, Lagos or Baghdad.” Equally important, FSO is not affected by rain, which can be a problem for a number of technologies (readers of our features on satellite communications may remember that Ka band can be interrupted by West Africa’s monsoons). It’s all a matter of physics, which is why no wireless technology is totally reliable and also why companies like Wireless Excellence work with a number of them. As Patrick says, “There isn’t just one technology that just works and one that doesn't.” So why not go for wired? Fibre, say? “Fibre is a perfect medium,” Patrick agrees. “When it’s installed and not interrupted you have a piece of glass that carries gigabits, even, terabits.” The trouble comes when you have to dig the street up - and get permission to do so. The upfront costs can be huge. And if you move offices what do you do with the cable? If you’re using FSO, of course, you just take your boxes and reinstall them. Patrick adds, “Apart from the disruption caused to traffic and other street users, there will be pre-existing underground services, ducts, drains and other pipes which have to be worked around. And there is always the very real risk that subsequent work by other providers digging in the same locations may break.” Of course, Patrick adds, “Diverse resilient media is always good a good thing to have in any network – wired or wireless.” That is, if the rooftop connection is undermined the underground connection probably won't be, and vice versa. But a private fibre system just isn’t possible in Cairo. In any case, BP
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THE UNITED REPUBLIC OF TANZANIA
Announcing the 4th Tanzania 2013 Licensing Round Deep Offshore | North Lake Tanganyika
The Government of the United Republic of Tanzania through Tanzania Petroleum Development Corporation (TPDC) is pleased to announce the 4th Tanzania Deep Offshore and North Lake Tanganyika Licensing Round. The delayed 2012 round was launched during the 2nd Tanzania Oil and Gas Conference and Exhibition.
Round Close:
Thursday, 15 May 2014, Dar es Salaam
4TH TANZANIA OFFSHORE AND NORTH LAKE TANGANYIKA LICENSING ROUND
The round includes the deep offshore sedimentary basins comprising of seven blocks (averaging 3000 sq km: Blk4/2A, Blk4/3A, Blk4/3B, Blk4/4A, Blk4/4B, Blk4/5A, Blk4/5B) and is located between 2000 m to 3000 m of water depths from 40°30’E to 41°40’E and 7°30’S to 9°00’S. Blocks 4/1B and 4/1C are reserved for the TPDC to execute exploration using a strategic partner. The blocks have excellent coverage of modern regional 2D seismic data available from ION Geophysical and WesternGeco. The North Lake Tanganyika block is located offshore in the western arm of the east African rift system. Lake Tanganyika is the world's longest (650 km) and second-deepest (1500 m) and is covered by sparse 2D seismic data collected in the 1980s during the African Lakes Drilling Project. The data and copy of report will be made available.
Tanzania Petroleum Development Corporation Contact: Mr. Yona Killagane Email: tpdc4round@tpdc-tz.com
ION Geophysical, Inc.
WesternGeco
Contact: Nick Blake Phone: +44 7734 415105 Email: nick.blake@iongeo.com
Stewart Walter Phone: +44 1293 556533 Email: swalter@exchange.slb.com
www.tz-licensing-round.com
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has appropriate back-up for its FSO system in the shape of lower-speed leased lines, just to keep basic services ‘up’ should the high speed gigabit FSO network experience any downtime, such as planned maintenance. FSO also involves a financial incentive for a corporate customer. Rather than a lease on its balance sheet as an ongoing loss every month it is buying an asset. ”That’s a capital purchase,” Patrick explains. “They own the boxes - a tangible asset - which increases the net worth of company. Leased lines do not.”
High speed
Of course what the BP offices are transmitting to each other may come to the FSO boxes from undersea cable, the PSTN’s own fibre links, a dedicated circuit, satellite, you name it. The point is that when it is passed it between buildings the wireless connection needs to be able to handle high speed and high volume in order to cope with the sort of data that could be involved. With FSO you have up to a gigabit a second to play with. So, Patrick says, “What can a gigabit do for you?” Answering his own question, he continues, “It can connect thousands of people - not just a few people in a branch office. And these are big BP offices.” Would that include a high definition rich multimedia file or high-resolution
photography of a wellhead? “You could share extremely rich multimedia content instantly without slowdown. That gigabit is the same speed that you have in your core switch in your network. It’s the same speed coming out of the server where that data is. We're not providing a bottleneck. So the user who’s in the building without the wireless is having the same speed experience as the guy who's at the other end of the wireless link.“ Demand for wireless alternatives is unlikely to slow down. After all, everything now goes down one channel. “We used to sell products that had 100 megabits of data and a side channel of two megabits to the telephones. You knew from install that one lot would be plugged into an Ethernet switch for LAN and the second lot would be plugged into a phone exchange for the voice and those would be entirely separate systems. That’s no longer the case. “ Now voice (over IP), internet, CCTV cameras and more can all be bundled together. “In essence we’re the providers of transparent fat pipes and users use them for all sorts of diverse things but I think it’s fair to say that everything these days is being put down a pipe.” That doesn't just refer to the traffic but how it is managed and used; therefore quality of service [QoS: minimum
KNPC implements Oracle for refinery expansion KUWAIT NATIONAL PETROLEUM Company (KNPC), a subsidiary of the State-owned Kuwait Petroleum Corporation, has completed a largescale upgrade of its data centre infrastructure based on Oracle SPARC T4 and M9000 servers. KNPC runs Kuwait’s oil refining and gas liquefaction operation in addition to distributing petroleum products in Kuwait through a chain of filling stations. This project was integral to the strategy of the KNPC IT department to fulfil its vision to add value to the core www.knpc.com.kw business and jointly transform KPC Downstream into a digitally intelligent corporation. The additional data centre capacity and scalability is needed to accommodate the immediate future requirements of corporate applications as well as the anticipated increased data load associated with the building of its new refinery and the roll-out of its clean fuel project. The additional capacity and expandability provided by the new data centre infrastructure will absorb the IT requirements of the new refinery, one of the largest strategic projects in the state of Kuwait with capacity for refining 615 000 barrels per day (bpd). The new refinery is intended to supply power generation plants in Kuwait with environment friendly fuel and provide an alternative for gas imports and heavy fuel consumption. In addition the servers will support the upgrades planned for KNPC’s Mina Abdulla and Mina Al-Ahmadi refineries, which will include installing reactors and vessels to process environmentally-friendly fuel with a low sulfur content. KNPC was able to reduce its real estate and power consumption by replacing old servers that had high power and cooling requirements with SPARC T4 servers running Solaris 11 with Oracle VM virtualisation.
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requirements on all the aspects of a connection], security, VLANs, VPNs and various other needs may have to be accommodated. And the amount of that ‘everything’ will grow. Patrick speaks of one East African mobile operator that coped fairly well with traffic volume for years, much of which could be backhauled comfortably around the network by a modest provision of wired or wireless link. Then the SEACOM undersea fibre optic link arrived and enabled high capacity communications. When people realised they could look at YouTube on their phones, bandwidth shot up, and congestion has followed. However, as Patrick says, “Globally, all network operators are facing a huge challenge: You can’t put the genie back in the bottle.” And that is the reality of modern communications: higher volume and faster links are essential - and not just for missioncritical purposes of the sort BP can expect. Everyday consumers also want more from their providers. FSO, microwave, cellular, fibre and satellite and many other transmission media are all part of that provision in an increasingly connected world, whether for the oil and gas business or for the smartphone user on a street in Lagos or Cape Town. ■
Performance-driven solutions MIX TELEMATICS, A global provider of fleet and mobile asset management solutions delivered as software-as-a-service or SaaS, says that oil and gas companies in Qatar and the GCC can save up to 15 per cent on their fuel costs by implementing an effective fleet management solution. “We help multiple oil and gas customers achieve and sustain results like this through driver behaviour monitoring and driver training initiatives,” says Alan Hall, managing director of MiX Telematics (Middle East and Australasia). MiX Vision is a highly configurable video recording system that allows fleet managers to assess the circumstances at the time of an actual or reported incident. Attached to the inside of the vehicle’s windshield, it houses two tamper-resistant cameras: one road-facing and the other driver-facing. Integration with MiX Telematics’ FM Communicator enables the automatic upload of predefined events such as harsh braking, speeding or an impact. Two 15second video clips, one showing the driver and the other showing the road, are then made accessible to fleet managers at the end of each completed trip. Access to all footage is made available to fleet managers at the end of each completed trip, and high-resolution versions of the clips are available at the touch of button. The footage can also be leveraged for driver training initiatives.
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ď&#x192;¨ Communications & IT
The need for next-generation
seismic High-density, fullazimuth broadband surveys are paramount today for high-resolution seismic for reservoir development, raising new challenges in terms of acquisition design, logistics, quality, HSE and data management, says Ghiath Ajlani of CGG.
D
Figure 1. Progression towards pointsource/point-receiver seismic acquisition.
ESPITE THE FACT that wide-azimuth land 3D seismic developed that are potentially capable of recording as many as one (1) acquisition was introduced a couple of decades ago, the use million channels at a 2ms sampling rate. To optimize productivity and of sparse 3D seismic designs continued for some time to be economics these recording systems have been combined with dictated by economic and technical limitations leading to poortechnologies that allow for shooting above 20,000 vibrator points per quality and noisy seismic data. These design shortcomings were day and the achievement of very high trace densities. These exacerbated by source and receiver arrays that failed to fully avoid technologies offer the possibility to deploy symmetric wide-azimuth aliased organized noise such as ground roll and guided waves and high-density source and receiver land geometries and acquire non compromising the integrity of processing, imaging and reservoir aliased signal and noise benefiting from all offsets and azimuths. characterization results. Growing demand for accurate quantitative reservoir characterization High-density full-azimuth design for reservoir development has pushed seismic advancements towards Consistent with high-density seismic acquisition requirements, all high-density, full-azimuth, broadband and array-free solutions. This relevant design parameters have evolved exponentially. Adequate poses unprecedented challenges in terms of equipment design and crossline offset and receiver line interval result in a high number of operation, deployment of novel acquisition technologies, development receiver lines, longer in-line offsets and smaller bin size which directly of adapted real-time QC, optimization of advanced processing impact the number of active channels per line (Table 1). algorithms and of the ability to handle significantly increased data volumes. Super-crews meet these challenges Table 1. Comparison between achieved and possible High-Density specs successfully through high-density, pointHigh-density seismic design parameters Achieved Future source/point-receiver, wide-azimuth programs, no. of receiver lines per live patch 120 400 providing the finest subsurface resolution with receiver line length (km) 20 40 exceptional spatial and temporal bandwidths at no. of active channels per live patch 120,000 1,000,000 (at 2ms with the reservoir. Indeed, over the last decade, Sercel 10GB/s transverse) super crews have moved from arrays of Cross-line offset (km) 5 10 vibrators and receivers on a coarse grid to source and receiver line interval (m) 25 x 100 10 x 50 single-source/single-receivers on a fine grid source and receiver station interval (m) 7.5 x 7.5 5 x 5 (1 VP per SP) (Figure 1). As a result, channel capacity has increased significantly. To meet these source density per km2 1,600 20,000 challenges, cutting-edge high-density and hightrace density per km2 48,000,000 100,000,000 resolution recording systems have been nominal fold of coverage 4,800 20,000
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The advent of these new acquisition techniques and equipment capabilities has led to a considerable increase in spatial resolution and fit-for-purpose high-density designs that can be implemented with the following requirements: • large in-line offsets to image deeper targets combined with single-sensor and single-source recording with an option for digital array forming at the processing stage. This has a direct impact on the number of active channels per receiver line. • large cross-line offset to meet wide-azimuth acquisition requirements • Smaller source and receiver line intervals for higher fold, reduced noise leakage and enhanced S/N. These high-density specifications have proven to be very beneficial in resolving subtle reservoir variations for mapping porosity, small faults, fracture density and direction, lateral stratigraphic anomalies and in some cases static and dynamic fluid contacts and 4D flood front advancements. Naturally, the ability to implement these wide patches with numerous receiver lines and massive equipment requirements depends on the suitability of the project terrain, the budget and time limitations.
Logistical and operational challenges
High-density acquisition seismic surveys by their very nature require the use of a tremendous amount of recording equipment of up to 200,000 geophones and the management of multiple fleets of vibroseis units with back-up, typically up to 20 vibrators. To handle these hundreds of thousands of sensors, manage the fleets of Vibroseis trucks and run the extensive infrastructure, a sufficient labor force and skilled expert personnel (typically up to 500 per crew) are working together in the field ensuring that the high-productivity levels inherent in high-density surveys are met (Figure 2).
Figure 2. a) Geophone testing at camp, b) geophone receiver stack before lay out. c) point-source Vibroseis 1VP per shot point spread, and d) up to 500 staff per crew. Strict project management and rigorous adherence to the highest HSE and quality procedures and standards are more than essential to ensure the success of any seismic acquisition of this type. The fleet size, equipment requirements and crew organization are directly linked to survey design and scope of work as per the desired results. Accordingly, a Value-of-Information (VOI) probabilistic decision tree analysis is recommended to ascertain the expected benefits of such a huge expenditure compared to gained value. 178
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High-density single-source, single sensor seismic acquisition is appropriate only when the value is proven.
Exponential increase in data volumes and QC
In addition to the numerous logistical and operational challenges, the sheer data volumes generated on a daily basis present another challenge in terms of data management, quality control and in-field processing. Properly sized recording and in-field processing equipment is vital for normal progress of data acquisition, quality control and processing. The base camp IT requirements for high-density seismic acquisition can be as high as 32 nodes with 4-8 processors each, 120 TB of storage capacity and processing of 4-8 TB of data daily. The final volume of data for processing can be as large as 1000 TB depending on survey size. To process such volumes in the field, up to 8 QC staff can be required on site. Field QC and processing of high-density 3D seismic data include numerous steps for ensuring accuracy of source and receiver geometry and positioning, coupling quality, enhanced S/N measures and eventually early volumes of pre and post stack data including signal processing and imaging.
Proven benefits in the Middle East
There have been recent successes with high-density single-source, single-sensor 3D land seismic acquisition that have led to tangible value and benefits for field development in the following areas: • Provides array-free un-aliased recording with no negative array effects. • Generates elementary single traces for surface-consistent true 3D high-resolution wide-azimuth processing with excellent spatial sampling and redundancy of millions of traces per km². • Assures an extremely well sampled wide-azimuth geometry which avoids the imprint of shallow anomalies at reservoir level. This is assisted by highly detailed modeling and compensation of surface and near-surface variations. • Achieves unrivaled spatial and temporal resolution revealing thinner beds and smaller faults, providing a more detailed understanding of the reservoir than ever before (Figure 3). ■
Figure 3: Conventional vs. high-density (CGG UltraSeisTM) land seismic for finer spatial sampling, wider bandwidth and superior resolution. Courtesy of Qatar Petroleum, Seeni et al, EAGE 2011. Acknowledgements The authors are grateful to CGG for permission to publish this paper. References Seeni, S. et. Al. Ultra High-density Full Wide-azimuth Processing Using Digital Array Forming - Dukhan Field, Qatar. EAGE Vienna, 2011.
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SPE is where you are.
All over the world Our membership combines the brightest minds in the E&P industry, giving you access to new people, new places, and new ideas from all over the world. And when you join SPE, you also join your local section. So, you can meet regularly with other members in your area to exchange ideas and discuss common issues. SPE has something for everyone working in the upstream oil and gas industry, no matter where on the globe you may be.
Join our worldwide membership today at www.spe.org/go/ORME
Society of Petroleum Engineers
S28 ORME 7 2013 DMS - Rig count_Layout 1 01/11/2013 18:41 Page 180
RIG COUNT ď&#x192;§
Middle East & North African 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.
Country
Land
Middle East IRAQ KUWAIT OMAN PAKISTAN QATAR SAUDI ARABIA SYRIA UAE - ABU DHABI UAE - DUBAI YEMEN JORDAN TOTAL
North Africa ALGERIA EGYPT LIBYA TUNISIA TOTAL
THIS MONTH OffShore Total
VARIANCE From Last Month
LAST MONTH Land OffShore Total
Land
LAST YEAR OffShore Total
93 29 56 21 5 61 0 19 0 4 1 289
0 0 1 0 4 19 0 11 1 0 0 36
93 29 56 21 9 80 0 30 1 4 1 324
0 5 -23 0 1 0 0 -4 0 -2 0 -23
93 34 33 21 4 61 0 18 0 6 1 271
0 0 1 0 6 19 0 8 1 0 0 35
93 34 33 21 10 80 0 26 1 6 1 305
70 31 50 14 2 63 27 20 0 4 0 281
0 0 1 0 4 18 0 7 0 0 0 30
70 31 50 14 6 81 27 27 0 4 0 310
46 42 11 2 101
0 5 1 0 7
46 47 12 2 107
3 2 3 -1 7
49 41 15 1 106
0 8 0 0 8
49 49 15 1 114
24 51 13 5 93
0 13 0 0 13
24 64 13 5 106
Source: Baker Hughes
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Issue 7 2013
S28 ORME 7 2013 DMS - Rig count_Layout 1 01/11/2013 18:41 Page 181
Project Databank Compiled by Data Media Systems
OIL, GAS AND PETROCHEMICAL PROJECTS Project
Facility
Budget ($ US)
Country
Status
Tacaamol Aromatics Olefins
Aromatics
800000000
U.A.E.
FEED
VOPAK HORIZON - Fujairah Oil Terminal Expansion (Phase 7)
Gas Storage Tanks
200000000
U.A.E.
EPC ITB
GASCO - HP Pipeline Connections - CNG Filling Stations
Gas
100000000
U.A.E.
Engineering &
Dana Gas - Zora Gas Field
Gas Exploration
100000000
U.A.E.
EPC ITB
ADCO - North East Bab (NEB) -
Oil Production
500000000
U.A.E.
EPC ITB
Emirates LNG - Fujairah LNG
Liquefied Natural Gas (LNG)
1000000000
U.A.E.
EPC ITB
ADCO - Nitrogen Gas Injection (NGI)
Gas Production
50000000
U.A.E.
Engineering &
Al Hosn Gas - Onshore Shah Sour Gas Field Development
Acid Gas
47000000
U.A.E.
Engineering &
GASCO - Habshan-Maqta-Taweelah Gas Pipeline
Gas
150000000
U.A.E.
Engineering &
Habshan - Ruwais 16-inch Condensate Replacement Pipeline
Gas Pipeline
90000000
U.A.E.
Engineering &
ADMA-OPCO - SARB Offshore Oil Field Development - Package 4
Gas Processing
500000000
U.A.E.
Engineering &
EMAL - Combined Cycle Power Plant - Phase 2
Power Plant
650000000
U.A.E.
Engineering &
Al Hosn Gas - Onshore Shah Sour Gas Field
Acid Gas
5500000000
U.A.E.
Engineering &
Acid Gas
1200000000
U.A.E.
Engineering &
Al Hosn Gas - Onshore Shah Sour Gas Field Development - (Overview)
Acid Gas
12000000000
U.A.E.
Engineering &
ADCO - Rumaitha North CO2 Injection Project
Oil Field Development
100000000
U.A.E.
EPC ITB
ADMA-OPCO - Umm Al Lulu Field Development - Package 2
Oil Field Development
500000000
U.A.E.
Engineering &
MASDAR - Carbon Dioxide Capture and Storage -
Carbon Dioxide
280000000
U.A.E.
Engineering &
Carbon Dioxide
300000000
U.A.E.
EPC ITB
MASDAR - Carbon Dioxide Capture and Storage - Phase I (Overview)
Carbon Dioxide
2500000000
U.A.E.
Engineering &
MASDAR - Carbon Dioxide Capture and Storage -
Carbon Dioxide
280000000
U.A.E.0
Engineering &
Polyolefins
1450000000
U.A.E.
Construction
and Nitrogen Chemicals - Aromatics Complex
Procurement
Rumaitha - Shanayel - Al Dhabbiya - Phase III
Procurement (Package 1 - Gas Gathering Facility)
Procurement Procurement Procurement Procurement Procurement
Development (Package 2 - Main Process Plant) Al Hosn Gas - Onshore Shah Sour Gas Field
Procurement
Development (Package 3 - Sulphur Recovery Units)
Procurement Procurement
Procurement Phase I (Mussafah Steel Rolling Mill) MASDAR - Carbon Dioxide Capture and Storage -
Procurement
Phase 2 (Pipeline Network) Procurement Phase I (Pipeline Network) BOROUGE - Borouge III - Polyolefins
Procurement
Borouge III (Overview)
Polyolefins
4500000000
U.A.E.
Construction
TAKREER - Expansion of Aviation Fuel Depot at
Oil Storage Tanks
200000000
U.A.E.
EPC ITB
Oil Storage Tanks
50000000
U.A.E.
Engineering &
Tacaamol Aromatics Olefins and Nitrogen Chemicals Project (Overview) Petrochemical Plant
10000000000
U.A.E.
FEED ITB
ADMA-OPCO - Umm Al Lulu Field Development - (Overview)
Oil Field Development
2000000000
U.A.E.
EPC ITB
Gasco - Integrated Gas Development (IGD) - Expansion
Gas Production
12000000000
U.A.E.0
Feasibility Study
IPIC - Fujairah Refinery
Refinery
5000000000
U.A.E.
FEED
TAKREER - Ruwais Flare Gas Recovery
Gas Processing
150000000
U.A.E.
Engineering &
ZADCO - Zirku 7th Crude Oil Storage Tanks
Oil Storage Tanks
30000000
U.A.E.
EPC ITB
Abu Dhabi International Airport Petrochem - Jebel Ali Chemical Storage and Distribution Terminal Expansion
Procurement
Procurement Fujairah Port Facilities Expansion
Oil Storage Tanks
100000000
U.A.E.
Construction
ZADCO - Umm Al Dalkh Full Field Development
Oil Field Development
650000000
U.A.E.
EPC ITB
S28 ORME 7 2013 DMS - Rig count_Layout 1 01/11/2013 18:41 Page 182
Project
Facility
Budget ($ US)
Country
Status
ZADCO - Upper Zakum Full Field Development (Dredging Package)
Oil Field Development
635000000
U.A.E.
Construction
Horizon Terminals - Falcon Jetfuel Pipeline & Bulk Terminal Facilities
Bulk Storage
127000000
U.A.E.
Engineering &
TAKREER - Ruwais Lube Base Oil Facility
Base Lube Oil
700000000
U.A.E.
Engineering &
ADMA-OPCO - Umm Al Lulu Field Development - Package 1
Oil Field Development
500000000
U.A.E.
Engineering &
ADCO - Field Development Program - Bab Field -
Exploration
400000000
U.A.E.
Engineering &
ADGAS - Das Island Pentane Storage Facility
Gas Storage Tanks
65000000
U.A.E.
Engineering &
Dana Gas - Sharjah and Ajman New Gas Field
Unknown
Gas Field Development U.A.E.
Procurement Procurement Procurement Habshan 1 - Phase 1- (EPC2)
Procurement Procurement Feasibility Study
GASCO - Habshan Direct Depressurization (HDD1)
100000000.
Gas Processing
U.A.E.
EPC ITB
ADCO - Bab Field Gas Compressors Installation - Phase 2
Gas Production
500000000
U.A.E.
Engineering &
ADMA-OPCO - SARB Offshore Oil Field Development -
Oil Production
260000000
U.A.E.
Engineering &
ADMA-OPCO - Zakum Facilities for 4 Gas Injectors
Gas Production
100000000
U.A.E.
EPC ITB
ZADCO - Satah Field Development - Main Construction Package
Oil Production
500000000
U.A.E.
Engineering &
ZADCO - Upper Zakum Full Field Development - 750 Project (Overview) Oil Field Development
5000000000
U.A.E.
Engineering &
ZADCO - Upper Zakum Full Field Development -
Oil Field Development
1300000000
U.A.E.
Engineering &
Oil Storage Tanks
130000000
U.A.E.
Engineering &
Oil Storage Tanks
100000000
U.A.E.
EPC ITB
TAKREER - Hamriyah Free Zone Tank Farm
Oil Storage Tanks
250000000
U.A.E.
Engineering &
ADMA-OPCO - Das Island Flares Modifications - Revamp Project
Gas Processing
50000000
U.A.E.
Construction
ADMA-OPCO - SARB Offshore Oil Field Development - Package 2
Oil & Gas Field
500000000
U.A.E.
EPC ITB
Ruwais Refinery Expansion (Package 2 -
Refinery
3100000000
U.A.E.
Engineering &
Ruwais Refinery Expansion (Package 3 - Offsites and Utilities)
Offsites & Utilities
2730000000
U.A.E.
Engineering &
TAKREER - Ruwais Refinery Expansion (Overview)
Refinery
10000000000
U.A.E.
Engineering &
CONCORD ENERGY - Petroleum Storage Facility
Oil Storage Tanks
250000000
U.A.E.
Engineering &
GASCO - Yas Mina Zayed Gas Pipeline
Gas Processing
45000000
U.A.E.
Engineering &
GASCO - Habshan Acid Gas Flaring Recovery
Gas Processing
100000000
U.A.E.
Engineering &
GASCO - Habshan Nitrogen Generation and Injection
Nitrogen
160000000
U.A.E.
Engineering &
Hamriya Jetty and Pipeline Network Project - Marine Works 2
Oil Storage Tanks
250000000
U.A.E.
Engineering &
ZADCO - Upper Zakum Full Field Development -
Oil Production
4200000000
U.A.E.
Engineering &
ADMA-OPCO - Das Island Flaring & Emission Reduction
Gas Production
100000000
U.A.E.
Engineering &
BOROUGE - Borouge III - Flare Gas Recovery
Gas Processing
150000000
U.A.E.
Engineering &
ADMA-OPCO - 100 MBD DAS Facilities Upgrade Project
Oil Field Development
48000000
U.A.E.
Engineering &
ADMA-OPCO - Nasr Field Development - (Overview)
Oil Field Development
3000000000
U.A.E.
Engineering &
ADCO - Sahil-Asab-Shah (SAS) Full Field Development - (Overview)
Oil Field Development
3750000000
U.A.E.
Engineering &
Procurement Artificial Islands - Package 1
Procurement
Procurement Procurement 750 Project - Surface Facilities - EPC 1 Socar Aurora Fujairah Terminal -
Procurement
Fujairah Oil Storage Terminal - Phase 2 Socar Aurora Fujairah Terminal -
Procurement
Fujairah Oil Storage Terminal - Phase 3 Procurement
Residue Fluid Catalytic Cracking Unit)
Procurement Procurement Procurement Procurement Procurement Procurement
Project (NGI Package)
Procurement Procurement
750 Project - Surface Facilities - EPC 2
Procurement Procurement Procurement Procurement Procurement Procurement
S28 ORME 7 2013 DMS - Rig count_Layout 1 01/11/2013 18:41 Page 183
S28 ORME 7 2013 DMS - Rig count_Layout 1 01/11/2013 18:41 Page 184
Project Focus Compiled by Data Media Systems
Project Summary Project Name
Tacaamol Aromatics Olefins and Nitrogen Chemicals - Aromatics Complex
Name of Client
Tacaamol
Budget ($ US)
800,000,000
Award Date
Q3-2014
Facility Type
Aromatics
Status
FEED
Start Date
Q4-2012
End Date
Q4-2017
Location
Abu Dhabi, U.A.E.
Project Backgrounds Tacaamol Aromatics Olefins and Nitrogen Chemicals plans to convert 3 million tons per year of heavy and medium naphtha, supplied via pipeline from the Takreer Ruwais Refinery, into paraxylene, mixed xylenes and benzene.
Project Status Sep 2013
CH2M HILL awarded the FEED contract.
Jul 2013
Project is still in early phase, the tender progressing scheduler is still not finalized.
27 Nov 2012
Tender for the EPC contract expected Q1 2014. FEED bids deadline date not yet decided.
Sep 2012
Invitation to bid for the FEED contract has been released.
Jul 2012
FEED tender has been cancelled.
30 Apr 2012
Foster Wheeler awarded the project management contract. Scope will also cover project management on FEED and EPC stages.
Project Scope The project includes converting 3 million tons per year of heavy and medium naphtha, supplied via pipeline from the Takreer Ruwais Refinery into : paraxylene, mixed xylenes, benzene.
Project Finance Tacaamol is the project client. Tacaamol is owned by: Abu Dhabi National Chemicals Company (Chemaweyaat), 51% International Petroleum Investment Council (Ipic), 49%
Project Schedules 4Q-2017
Completed
S29 ORME 7 2013 Arabic_Layout 1 01/11/2013 15:52 Page 185
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¤GE á˘LÉ◊G ,∫ƒ˘≤˘ë˘∏˘d ó˘jGõ˘àŸG è˘°†æ˘dG äGQɢ ˘ ª˘ ˘ ˘ã˘ ˘ ˘à˘ ˘ ˘°S’G ø˘ ˘ ˘e ó˘ ˘ ˘jõŸG ï˘ ˘ ˘°V êGôîà°S’G äÉ«æ≤J ∫É› ‘ áªî°†dG Ωó˘ bGCh ÈcGC ø˘ e ¢m†©˘ H ‘ §˘ Ø˘ ˘æ˘ ˘∏˘ ˘d ø˘ ˘°ùÙG ∫ƒ˘≤˘M ô˘jƒ˘£˘J ÖfɢL ¤GE Gò˘g .âjƒ˘μ˘dG á˘dhó˘H ∫ƒ˘≤◊G ácô°T âfÉY ó≤dh .OÓÑdG ∫ɪ°ûH á©bGƒdG á∏«≤ãdG ábÓª©dG §ØædG á«àjƒμdG ∫hÎÑdG á°ù°SƒDŸ á©HÉàdG á«æWƒdG ácô˘°ûdG »˘gh ,᢫˘à˘jƒ˘μ˘dG §˘Ø˘æ˘dG AGÈÿGh äGÈÿG ¢ü≤f øe á∏jƒW IÎØd ,êÉàf’EGh Ö«≤æàdG ´É£b ‘ á°ü°üîàŸGh º°V ¤GE É°†jGC á«∏jƒëàdG äÉYÉæ°üdG ´É£b êÉàëj ,¬JGP âbƒdG ‘h .ôe’CG Gòg ‘ πeÉ©eh ‘É°üŸÉa .∂dòc IójóL ¥Gƒ˘°SGC hõ˘Zh Ió˘jó÷G ɢ«˘Lƒ˘dƒ˘æ˘μ˘à˘dG ø˘e ó˘jõ˘e .¥Gƒ°S’CG ¬«dGE êÉà– …òdG ≈≤f’CG OƒbƒdG êÉàfGE πLGC øe ÊÉ©Jh á≤«àY Èà©J ôjôμàdG Ö«≤æàdG ´É£b πãe ,êÉà– »¡a .äÉjhɪ«˘chÎÑ˘dG á˘YÉ˘æ˘°üd á˘Ñ˘°ùæ˘dɢH ô˘e’CG ∂dò˘c äGƒæ°ùdG ∫ÓNh .É¡LÉàfGE IOƒL Ú°ù–h IójóL ¥Gƒ°SGC øY åëÑdG ¤GE ,êÉàf’EGh ¿Éc ó≤a .âjƒμdÉH ¥ÉØNGE »qàdÉM ÈcGC á«∏jƒëàdG äÉYÉæ°üdG ´É£b ó¡°T ,IÒN’CG ‘ Iôe ∫h’C ,É«eƒj π«eôH ∞dGC 615 èàæJ »àdG ,QhõdG IÉØ°üe ´hô°ûe åëH ” ób øe ÒãμdG äó¡°T É¡fGC ÒZ .2012 ‘ πª©dG GCóÑJ ¿GC ô¶àæŸG øe ¿Éch ,2008 ΩÉY IÉØ°üŸÉH πª©dG ¥Ó£fG ïjQÉJ ¿ƒμj ¿GC ™bƒàŸG øe íÑ°UGCh ,áªî°†dG äÉ°SÉμàf’G ≥˘«˘≤– ᢫˘dɢª˘à˘MG ¤GE Ò°ûJ QOGƒ˘H ∑ɢæ˘g ¿GC ` ∂dP ™˘e ` hó˘Ñ˘j ø˘μ˘d .2018 ΩɢY ƒ˘g ó©H ÉghDɨdGE ” ºK á«Hƒæ÷G ÉjQƒc øe äÉcô°T ≈∏Y Oƒ≤Y AÉ°SQGE ” ó≤a .Ée Ωó≤J IóëàŸG áμ∏ªŸÉH ácô°T ¿GC ’GE ,»°VÉŸG ó≤©dG øe IÒN’CG äGƒæ°ùdG ‘ ∂dP .Ò°ü≤dÉH ¢ù«d øeR òæe ¬ëæe ” »°Sóæg ó≤Y ∫hÉCH RƒØdG ‘ âë‚ ,á«dhÎÑdG äÉjhɪ«μdG áYÉæ°U ácô°T â°Vôq©J ó≤a ,äÉjhɪ«chÎÑdG ∫É› ‘ ÉeGC øjôªãà°ùe ™e áªî°V á≤K áeR’C ,á«àjƒμdG ∫hÎÑdG á°ù°SƒDŸ á©HÉàdG äÉcô°ûdG ióMGE ¥Ó˘ª˘Y ÚHh ɢ¡˘æ˘«˘H ∑ΰûŸG ´hô˘°ûŸG ø˘ e ɢ ¡˘ Hɢ ë˘ °ùfG Üɢ ≤˘ YGC ‘ ∂dPh ,Ú«˘ dhO QÉ«∏e 17^4 ᪫≤H ¿Éc …òdGh 2008 ΩÉY ôNGhGC ‘ ä'Éjhɪ«μ∏d hO' IóëàŸG äÉj’ƒdG á∏«∏b ΩÉjGC πÑb ÜÉë°ùf’G çóM ,»∏NGódG »°SÉ«°ùdG §¨°†∏d áé«àfh .»μjôeGC Q’hO äɢYɢ£˘b á˘aɢc ≈˘∏˘Y √Qhó˘H ô˘KGC …ò˘dG ô˘e’CG ,ɢ«˘∏˘©˘a ∑ΰûŸG ´hô˘°ûŸG ¥Ó˘£˘fG ø˘e á«ÑæL’CG äGQɪãà°S’G ‘ ΩÉJ π∏°ûH áHÉ°UGE ∂dP øY âéàfh .ádhódÉH §ØædG QÉμàMG äÉjhɪ«μdG áYÉæ°U ácô°T ΩGõdÉEH ,»°VÉŸG ΩÉ©dG ‘ ,º«μëàdG ≈¡àfG ≈àM Iô°TÉÑŸG É°†jƒ©J á«μjôe’CG hO ácô°ûd »μjôeGC Q’hO QÉ«∏e 2 øe Üô≤j Ée OGó°ùH á«dhÎÑdG .ÉgôFÉ°ùN øY ,É«Ñ°ùf øe’BG ,…OÉ°üàb’G ∞bƒŸG ™é°ûj ¿GC øe ÖfÉL’CG ¿hôªãà°ùŸG »°ûN óbh áHƒ∏£ŸG πL’CG á∏jƒW äGQÉ¡ŸGh É«Lƒdƒæμà˘dG äɢLɢ«˘à˘MG ∫ɢª˘gGE ≈˘∏˘Y Ú«˘°Sɢ«˘°ùdG äõéY ó≤dh .¿’BG ¤GE IóFɢ°ùdG »˘g á˘dÉ◊G √ò˘g ¿ƒ˘μ˘J ó˘bh .Rɢ¨˘dGh §˘Ø˘æ˘dG ´É˘£˘≤˘d IójóL ôjƒ£J äɢYhô˘°ûe …GC ò˘«˘Ø˘æ˘J ‘ ɢeó˘b »˘°†ŸG ø˘Y ᢫˘à˘jƒ˘μ˘dG §˘Ø˘æ˘dG á˘cô˘°T ‘ π«eô˘H ÚjÓ˘e 4 ¤GE »àjƒμdG ΩÉî∏d á«LÉà˘f’EG IQó˘≤˘dG ™˘aô˘d á˘jQhô˘°Vh á˘ª˘î˘°V êÉàëj ó≤a .(π©ØdÉH äGôe IóY ¬∏jó©J ” …òdG ±ó¡dG ∂dP) 2020 ∫ƒ∏ëH Ωƒ«dG ≈ª¶©dG á«ÑdɨdG iôj …òdG A»°ûdG ƒgh ,ôgÉe »ÑæLGC ∂jô°T OƒLh ¤GE ∂dP ≥«≤– .âjƒμdG ‘ OQGƒª∏d ΩQÉ°üdG »eƒ≤dG §î∏d GÒÑc Gójó¡J πãÁ ¬fGC Ú«fÉŸÈdG øe á∏eÉ©dG ,á«àjƒμdG á«æWƒdG ∫hÎÑdG ácô°T â¡LGh ,á«∏jƒëàdG äÉYÉæ°üdG ´É£b ‘h Aɢ°SQGE ¿ÉC˘°ûH π˘°UGƒ˘à˘dG ‘ äGCó˘H ɢ¡˘fGC Oô˘éà Oɢ°ùØ˘dɢH ɢeɢ¡˘JG ,ô˘jô˘μ˘à˘dG ∫É› ‘ ΩGóîà°S’ ¿ÉŸÈdG É¡«dGE ÉCé∏j á≤jôW øY IQÉÑY ∂dP πc ¿ƒμj óbh .ºî°V ´hô°ûe ¬d ¢ù«d …òdG ∫ÉÛG ƒgh ,RɨdGh §ØædG ´É£b ≈∏Y ¬°ùØf ¢VôØd á«dÉ◊G ¬JÉ£∏°S IQó≤dG äó¡°T ,¬∏c ∂dP ºZQh ,øμd .ájô¶ædG á«MÉædG øe ,¬«∏Y á£∏°S hGC ÒKÉCJ ¤GE ` ∫ɢª˘L’EG ‘ ` ∂dP ´É˘LQGE ø˘μÁh .ɢkXƒ˘ë˘∏˘e Gƒ‰ âjƒ˘μ˘dɢH §˘Ø˘æ˘∏˘d ᢫˘Lɢà˘f’EG
S29 ORME 7 2013 Arabic_Layout 1 01/11/2013 15:52 Page 186
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S29 ORME 7 2013 Arabic_Layout 1 01/11/2013 15:53 Page 189
S29 ORME 7 2013 Arabic_Layout 1 01/11/2013 15:53 Page 190
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S29 ORME 7 2013 Arabic_Layout 1 01/11/2013 15:54 Page 195
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S29 ORME 7 2013 Arabic_Layout 1 01/11/2013 15:54 Page 196
S29 ORME 7 2013 Arabic_Layout 1 01/11/2013 15:54 Page 197
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Emerson Process Management......................7 Euroblast Middle East L.L.C. ..........................16 Europoles Middle East LLC ............................32 Expocentre Sharjah........................................175 Expotim International Fair ORG. INC (Basra Oil&Gas) ................................................63 Expro International Group PLC (ADIPEC 2013) ................................................120 FAS Flussiggas-Anlagen GmbH ................142 Flexpipe Systems ..........................................127 FourQuest Energy Inc....................................145 Frontiermedex....................................................59 Gardner Denver Machinery Inc. ..................38 General Atomics-Electronic Systems ........68 Global Pipe Company......................................34 Hart BV.................................................................81 Hi-Force Ltd. ......................................................31 Hisaka Middle East Co. Ltd. ........................125 Honghua Golden Coast Equipment FZE ....42 IIR Exhibitions (MEE 2014)..........................196 Index Conferences and Exhibitions ..........194 Inmarco Industries FZC ....................................8 Invensys Systems ............................................43 ION Geophysical ............................................173 Isisan ....................................................................48 John Zink International Luxembourg S.ar.l. ............................................55 Jotun Paints UAE Limited LLC ........................5 Kaeser Kompressoren FZE ............................73 Kallman Worldwide, Inc. (ADIPEC 2013) ................................................106 KCH Separation BV ..........................................71 Lapmaster International ................................46 LMS International (ADIPEC 2013) ............131 Magnetrol International N.V. (ADIPEC 2013) ................................................199 Magnum Technology Centre (MTC)..........151
Magus International......................................113 Marelli Motori SPA ..........................................23 Metscco Heavy Steel Industries Co. Ltd. ..83 Midas Safety Products Trading ..................142 Mineral Circles Bearings ................................64 Motherwell Bridge (ADIPEC 2013) ..........123 Mott MacDonald Ltd. ......................................66 MSA Middle East FZE......................................69 Nexans ................................................................21 Nordic Energy FZC............................................85 Nylacast ............................................................144 Oeltechnik (ADIPEC 2013) ............................75 OKI Europe Ltd................................................175 Oman Cement Company ............................147 Orbcomm..........................................................175 PFS Technologies ......................................37, 39 Prakash Steelage Limited ..............................27 Promineo AS (ADIPEC 2013) ......................133 R STAHL MIDDLE EAST FZE (Basra Oil&Gas) ................................................65 Raccortubi ........................................................104 RBV Energy ........................................................94 Rittal Middle East FZE ....................................52 Rumaila Energy Park ....................................159 Sabin Metal Corporation ................................41 Saga PCE Pte Ltd.......................................3, 107 Samson Controls FZE (ADIPEC 2013) ......100 SAUDI ABRASIVES ..........................................61 Saudi Leather Industries Company Limited ............................................84 Saudi Steel Pipe Company ..................87, 119 Schlumberger Oilfield Mktg Communications ................................................2 Schlumberger Technical Services Inc ..........6 Schneider Electric IT Logistic Europe (ADIPEC 2013) ................................................139 Schoeller - Bleckmann UK..........................103
Scomi Oiltools (Cayman) Limited ................89 Seco Tools UAE ................................................93 SFL Industries Stopaq B.V. ............................51 Shangri-La Hotel and Traders Hotel............11 Shree Steel Overseas FZCO ..........................10 Sica SpA ..............................................................50 SIME Srl (ADIPEC 2013)..................................96 Sledgehammer Oil Tools Private Limited..91 Society of Petroleum Engineers................179 Sofitel Al Khobar - The Corniche ................17 Spina Group Srl..................................................36 STAUFF - Walter Stauffenberg GmbH & Co KG (ADIPEC 2013)....................76 Sulzer Pumps Middle East ............................90 Suraj Limited......................................................31 T.D. Williamson SA ..........................................53 Technical Access Services LLC ..................109 Technip - Region Middle East (ADIPEC 2013) ..................................................95 Teddington Engineered Solutions Limited ..........................................113 Timberland..........................................................33 TMK Middle East ..............................................99 Top Oil Field Industries Ltd. FZC (ADIPEC 2013) ..................................................97 Trans Asia Pipeline Services FZC ................92 Tratos Cavi S.p.A. ......................................26, 54 Triplefast Middle East Limited ..................101 UK SAMPLING GAUGES LTD. ........................49 Ulterra Drilling ................................................165 Uni-Geräte E. Mangelmann Elektrotechnische Fabrik GmbH (ADIPEC 2013) ..................................................75 Valbruna Gulf FZE..........................................121 Van Beest B.V. ..................................................99 Vertex (ADIPEC 2013) ....................................72 VF Imagewear ................................................155
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Standn°: 11346
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