Oil, Gas and Shipping Magazine

ISSUE 70 www.ogsmag.com

Cover Story:

Dow Innovation:

Fueling Sustainability & Productivity

Konepaja H채kkinen Oy Konekuja 4, FI-21200 RAISIO Tel. +358 207 813 400 E-mail: email@konepajahakkinen.fi Website: www.konepajahakkinen.fi

ISSUE 70 www.ogsmag.com

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Cover Story Page: 6:

Dow Innovation: fuelling sustainability and productivity

Contents

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Cover Story:

Dow Innovation:

Fueling Sustainability & Productivity

EDITORIALS

Page 36 Kuwait National Petroleum: Integration and Excellence Page 40 BHP Billiton: A Leading Global Resources Company Tyco Fire and Integrated Solutions: Protecting Page 48

Life, Assets and The Environment

NEWS

Page 22 Glacier Energy Services appoints new heat transfer division MD ROVOP leader named UK entrepreneur of the year for Page 23 global growth Page 25 Chevron announces first gas from Bangladesh

Bibiyana expansion project Page 25 Chevron announces sale and joint venture partnership

for Duvernay shale assets in Canada with KUFPEC Page 26 BP reports third quarter 2014 results Joint shipping initiative funds new phase of anti- Page 28

piracy project in Somalia Page 31 Shell starts oil production from Gumusut-Kakap deep

water platform in Malaysia Page 33 Schlumberger introduces new well integrity service Page 34 Baker Hughes implement new policy of full chemical

disclosure for fracturing companies Page 34 BP and CGG agree to develop next generation marine

seismic source technology Page 46 Versa Dev

ADVERTISERS

Page 2 Konepaja Hakkinen Oy Page 5 Vastas Page 20 Enefit Technology Industries Page 21 The Heavy Lift Group Page 24 Exova Page 27 Technip Page 29 FMC Technologies

Page 30 Sikorsky Page 32 Emerson Process Management Page 35 Chart Industries Page 39 Van Oord Page 47 Versa Dev Page 54 Georg Schunemann GmbH Page 55 Saturn Gas Turbines Page 56 Vroon Offshore

Oil, Gas and Shipping 2014 Oil, Gas and Shipping Magazine is published by Worldwide Business Media Limited, London, EC1V 2NX United Kingdom. Registered No. 6809417 England/ Wales. VAT No. 972 7492 76. All rights reserved. Reproduction in whole or any part without written permission is strictly prohibited.

Liability: while every care has been taken in the preperation of this magazine, the publishers cannot be held responsible for the accuracy of the information herein, or any consequence arising from it. All paper used in this production comes from well managed sources.

Oil, Gas and Shipping Magazine Tel: +44(0)203 5751249 Sales email: info@ogsmag.com Editor email: editor@ogsmag.com

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Dow Innovation:

Fueling Sustainability & Productivity This is an exciting, and challenging, time to be part of the global oil and gas industry. Population growth, emerging economy urbanization and industrialization, freshwater scarcities, and environmental pressures are converging to generate enormous performance imperatives as the industry strives to meet the steadily rising worldwide demand for energy.

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Increasingly, operators are harvesting oil and gas from previously inaccessible sources, ranging from deeply embedded shale and oil sands to deep water and ever more high-temperature, high-pressure reserves.

New solutions are necessary to extract energy efficiently from these unconventional sources, and to enhance recovery from existing wells. Technologies are required to remove different contaminants from unconventional oil and gas sources, and to minimize emissions and overall environmental impact.

Water-intensive operations need innovative, economical solutions for minimizing water consumption, treating and disposing wastewater, and optimizing water acquisition and utilization processes.

The energy industry requires more innovative, productive and sustainable solutions that are less time, capital and physical resource intensive. These new challenges are complex and difficult for any single stakeholder to solve. They require multidisciplinary science and technology solutions – precisely what Dow offers the oil & gas and energy industries.

Norm Byrne, R&D Director of Dow Oil Gas & Mining and Larry Ryan, Business President of Dow Energy & Water Solutions

A respected partner in the global oil patch for more than 70 years, Dow understands these emerging challenges. For decades, the industry has relied on Dow’s advanced chemistry, engineering and materials science capabilities to help turn the biggest challenges into unique opportunities for maximizing production and optimizing efficiency while helping to minimize costs, resource consumption and emissions – from exploration and production to refining and distribution.

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Today, Dow is uniquely positioned to address local and regional hydrocarbon industry challenges worldwide.

Familiar with individual company and local needs, Dow’s oil and gas experts draw upon global R&D resources and decades of experience for customizing solutions and services tailored to the evolving needs our customers.

And Dow’s experts routinely leverage a first-class toolbox of technologies for addressing customer challenges:

• Dow’s branded systems and solutions for cost-effective, sustainable operations relating to exploration,

production, enhanced oil recovery, transportation, refining, gas processing and distribution are industry standards.

• With a broad portfolio of ion exchange resins, reverse osmosis membranes, ultrafiltration membranes and electrodeionization products – Dow spearheads the development of sustainable technologies that integrate water and energy requirements to help oil and gas customers optimize all phases of their water usage.

• Dow also offers the oil and gas industry a broad portfolio of innovative microbial control technologies to help maximize production quantity and quality, combat microbial formation damage and enhance site safety. An optimized biocides program can help control microbial growth and microbially influenced corrosion, reduce well and reservoir souring, and improve production and resource recovery safely and sustainably in a variety of hydrocarbon operations.

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Dow’s Community Approach Dow believes the health of its business is fundamentally intertwined with the social and economic health of every community and region where it conducts business. The company’s goal is to be perceived as a local company with global resources, not the reverse. For instance, after 40 years in the Middle East and North Africa region, Dow maintains seven offices, six manufacturing plants, two technical service centers and an R&D center … but numbers don’t tell the real story.

For more than 100 years, innovation has been the key to Dow’s ability to solve tough customer problems. Today, Dow is a global enterprise combining the power of science and technology to help address many of the world’s most challenging problems in more than 180 countries. With more than 10,000 active patents, 5,500 dedicated esearchers worldwide and a 2014 R&D budget of approximately $2.0 billion, Dow has deep and broad expertise in chemistry, analytical science, biotechnology, catalysis, ceramics, materials science, polymer science, separation science and engineering.

Dow recognizes that the source of its innovation prowess is the most valuable element of all – the human element. The company is continually seeking the best and the brightest scientific, engineering and commercial talent from around the world.

Dow’s growing team of local technical and commercial experts partner face-to-face with regional businesses on a daily basis. Dow’s people are intimately familiar with customer, community and regional challenges and aspirations. The company routinely delivers tailored regional solutions. For example, Dow is developing a high-temperature specialty solvent for gas treating designed to eliminate the need for cooling in hot climates – a product that has the potential to save Middle Eastern gas plants and refineries approximately 30 percent in both capital and operating costs, while minimizing environmental impact.

The company’s regional research center is based at King Abdullah University of Science and Technology (KAUST) in Saudi Arabia to support Dow’s goal of helping the country foster a knowledge-based economy. The R&D center is currently developing innovative, science-based solutions for challenges in the region’s water, energy and infrastructure industries – just one of many examples of Dow’s local initiatives for helping to build stronger, healthier communities throughout the region.

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Natural Gas Processing: More Productivity + More Efficiency Natural gas exploration, production and use have become a high priority worldwide for many reasons: it is a relatively clean-burning fuel and a valuable industrial feedstock; it is relatively abundant; it is comparatively inexpensive in certain regions; and it can be efficiently processed to pipeline specification for local use.

Consequently, natural gas is becoming the fuel of choice for industrial, power, and residential applications.

These and other factors have generated new technical and economic challenges that vary from region to region for natural gas processors. In North America, supply is close to outpacing demand, placing downward pressure on prices and operating margins. In gas-rich regions such as the Middle East, there is growing interest in using gas for domestic power generation by drawing from local reserves high in CO2, H2S, water and other impurities.

Tightening environmental regulations in many regions intensify the demand for cleaner gas solutions and efficient, cost-effective operations.

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Combined, these and other issues add up to one thing for natural gas processing: a critical need to maximize output and minimize costs.

With seven decades of experience in gas treating and more than 1,000 gas treating references worldwide, Dow recognizes the cost and performance pressures gas processors are facing today. The company’s team of research scientists and application engineers focus on helping customers around the world meet their unique gas specification and emission requirements, increase plant capacity, decrease capital and operating expenses, and extend asset life.

Solving customer efficiency and margin challenges is routine for Dow’s global team of experts, who draw upon one of the broadest portfolios of proven, reliable products for gas sweetening (heat management) and one of the broadest selections of gas treating technologies and services available. Dow is a leading manufacturer of amine and physical solvents used in gas sweetening processes for the selective removal of CO2, the selective separation of CO2 and H2S, mercaptan removal, bulk removal of acid gases, and acid gas removal from liquid hydrocarbons.

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The company’s UCARSOL™ and SELEXOL™ specialty solvents and alkanolamine offerings cover the widest range of gas impurities and treatment requirements for natural gas, unconventional gas, refinery gas, and liquid hydrocarbon treating. Dow’s experts routinely formulate solvents to provide specific acid gas removal performance for gases with widely varying H2S and CO2 content.

Dow is also the only gas treating solvent supplier providing a solvent purification system to reduce heat stable amine salts – the patented UCARSEP™ Process. This electrodialysis purification system treats a slipstream from the amine system while the system is still running to preserve the amine solution’s functionality, while avoiding costly shutdown time.

Many customers take full advantage of Dow’s AMINE MANAGEMENTS Program (AMP) for integrated gas treating processes – a comprehensive monitoring and maintenance system designed to help optimize amine usage, reduce emissions and energy use, maximize solvent life, and minimize contaminants and corrosion. Advanced technical support from Dow includes: simulation capabilities to model current and future gas treating needs; access to a state-of-the-art pilot plant that can reproduce processes; ongoing analytical support, including troubleshooting analytical capabilities; plus an experienced technical service team to assist with gas treating challenges as they arise.

Through AMP, Dow also offers customers comprehensive gas treatment solutions for all phases of a facility’s life cycle, including plant design, start-up and operational phases. For new or expanded liquefied natural gas (LNG) trains and gas treating facilities, Dow’s assistance begins with proprietary simulation capabilities for calculating optimal design and performance parameters. Dow works closely with contractors during construction, and helps train plant personnel to help ensure smooth, on-time start-ups. This free service is offered for all natural gas facilities, including many of the multi-billion dollar mega-projects recently completed

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in the Middle East for companies such as RasGas, GASCO, KNPC and others. These services are a major reason that the majority of LNG produced in the Middle East is processed using Dow technology.

Dow is also a leading supplier of high temperature heat transfer fluids and expert advice that helps customers reduce the piping and equipment size of their operations compared to steam systems. The company’s DOWTHERM™ line of heat transfer fluids are used extensively in the Middle East and globally to transfer heat from fired equipment generating the heat to process operations needing the heat. Recently DOWTHERM™ G was selected for the Saudi Aramco project called Shaybah. Dow offers low-temperature fluids for cooling loops, high-temperature fluids for heating loops, and silicone-based fluids for challenging operating conditions.

The company also offers sample analysis to ensure customer heat transfer fluids are performing at optimum conditions over a long period of time.

The company offers many other solutions for efficient gas processing, including cost-effective methods for removing scale, grease, and the hydrocarbon-agglomerated iron sulfide foulant common to amine systems; dessicants for dehydrating natural gas prior to transmission through pipelines; and coolants for freeze and burst protection. Whether customers are seeking total or selective acid gas removal, Dow has the know-how and technologies to evaluate unique needs, develop customized solutions, and provide experienced technical service and support.

Dow offers a broad range of solutions for the challenges of natural gas processing: amines, physical solvents, hybrid solvents, antifoams, glycols for dehydration, high temperature heat transfer fluids, low temperature heat transfer fluids, silicone based heat transfer fluids, reclamation technologies, and many others. his allows Dow to help customers select the best technology or combination of technologies for specific needs. Regional teams are available for quick response to customer requirements, with the backing of the global team to assist as required.

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EOR: More Oil, More Efficient Water Treatment As “easy oil” from established wells deplete over time, enhanced oil recovery (EOR) becomes an increasingly important strategy in terms of meeting global demand for energy and reaching company financial targets.

EOR techniques are especially water intensive – injecting large quantities of water into reservoirs at high pressures to stimulate 20 to 30 percent additional oil recovery from existing wells.

source waters for injection or produced and flowback waters for reuse or discharge. During the primary separation step, crude oil is treated with emulsion breakers that aid in removing water from water-in-oil emulsions. For instance, Dow’s DEMTROL™ line of emulsion breakers is widely used for quickly and efficiently enabling water removal from water-inoil emulsions to provide dry, on-specification oil.

This presents oil operators with water management issues for both onshore and offshore operations, including water acquisition, utilization, treatment and disposal. By volume, water production represents approximately 98 percent of the non-energy related waste produced by the industry, placing additional stress on limited global freshwater supplies.

Consequently, operators are actively seeking efficient technology and water strategy solutions for their EOR and other operations to help reduce costs, increase uptime, protect downstream assets and meet environmental requirements.

Water clarifiers are then used to further separate oil from water streams to meet regulatory discharge limits required for reinjection, disposal and reuse – but there are certain challenges involved. For instance, conventional clarifying technologies sometimes cause downstream issues, including water handling system fouling and the extraction of gel-like solids during and after the clarification step. Consequently, it is of the utmost importance that produced water is treated with precise, reliable chemistry that not only reduces solids and contaminants based on application perimeters, but also helps prevent pump and system fouling.

A range of advanced water systems and innovative chemistries are available to meet these objectives and efficiently remove solids from produced and flowback water, which have widely varying characteristics depending on location, formation geochemistry, and other factors. These technologies also open the door to broader water sourcing strategies, including brackish surface or groundwater, treated industrial or municipal wastewater, and recycled produced or flowback water.

Dow’s ROMAX™ 6000 and 9000 series of water clarifiers were designed to address these issues and help protect the chemical injection pumps used to dose them into the produced water stream by minimizing fouling.

While easy to use and apply, Dow’s clarifier chemistry also effectively streamlines treatment and increases operational efficiency, which can ultimately reduce operational costs, maintenance and handling. The treated, produced water helps meet regulatory oil and grease specifications, and can be re-injected, reused, or discharged back into the environment.

Dow offers a suite of products for chemical and miscible gas flooding in EOR applications. For instance, in heterogeneous reservoirs or those with mobility control issues or gravity override, producers can utilize Dow’s ELEVATE™ line of CO2 foaming surfactants to help improve CO2 conformance, enhance reservoir sweep, reduce CO2 cycling and lower gas-to-oil ratios.

To effectively apply the proprietary ELEVATE™ CO2 Enhanced Oil Recovery Conformance Solution, Dow’s technical service and support team offers reservoir evaluations and modeling, customized product selection and validation, economic evaluations and field implementation.

A variety of aqueous-based technologies are available today to facilitate complete or targeted removal of ionic, organic and particulate contaminants from

Today’s conventional clarifier technologies often are delivered either as a solid or as a hydrocarbonbased solvent. These products require inversion or a maintenance intensive dilution process which can take up to 18 hours of mixing time prior to dosing. Dow’s aqueous-based clarifiers can be dosed directly without inversion. ROMAX water clarifiers also eliminate the need for dilution or activation, which ultimately helps reduce operating expense. In fact, the ROMAX 6000 series of anionic, cationic and nonionic water clarifiers are fully formulated and ready to use as soon as they arrive at the field.

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Microbial Control Solutions Bacteria will grow just about anywhere water can be found. In hydrocarbon production and processes, the large volume of associated water provides an environment in which bacteria will thrive. Their presence impacts the quality and quantity of production, but also the safety of the operation. Microbes contribute to the souring of production, corrosion of pipelines and equipment, and the plugging of reservoir pore throats. Advanced stimulation techniques like hydraulic fracturing and enhanced oil recovery (EOR) are more water-intensive processes that provide opportunities for bacterial contamination if not properly controlled with a more advanced biocides program.

Dow provides one of the world’s broadest ranges of microbial control actives for oil and gas applications as well as state-of-the-art diagnostic techniques and expertise required for advanced sustainable microbial control. Dow works with multiple collaborators in the hydrocarbon value chain to design and implement novel applications that provide specific, yet extended, microbial control, all while facilitating minimal negative impact on the environment. Microbial control applications can be found all the way from reservoir treatment options to near wellbore treatments, ranging from hydraulic fracturing to topsides remediation of produced and recycled waters.

At Dow, treatments are designed to meet three important sustainability criteria: they do their job, do no harm, and go away.

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Shale Oil & Gas: More Water Reuse, More Sustainable The use of hydraulic fracturing to recover oil and gas from shale in North America, Australia and beyond has generated headlines, public concern, entrepreneurial speculation, and government action worldwide. Public concern has centered on possible groundwater contamination and potential overuse of scarce freshwater supplies. Globally, these concerns have limited hydraulic fracturing and production of shale reserves so far to the US, Canada, and Australia, with fledgling production in Argentina, China and Poland. With 32 percent of total estimated global natural gas reserves and 10 percent of estimated oil reserves in shale or tight formations, many other countries are interested in shale gas and tight oil recovery. Resolution of the public concerns and development of safe, sustainable water management in hydraulic fracturing is critical to the industry and our energy-dependent world.

The water issue surrounding hydraulic fracturing is part of the inescapable water-energy nexus: water is needed to extract hydrocarbons, and energy is required to produce usable water. Hydraulic fracturing can use more than five million gallons of water per well, which generally ranges from less than 0.1 to 0.8 percent of total water use by basin. Nevertheless, this level of water use can be significant in arid regions or areas experiencing drought.

Shale energy operators and regulators in many countries are working to find ways to supply water to the industry without disrupting farms, municipalities and local populations.

Of equal concern to the oil and gas industry is the need for precision water quality to ensure that unwanted salts and compounds do not interfere with performance of the fracturing liquid. Shale production water management issues can be summarized as finding economical and sustainable means for water acquisition, water utilization, and wastewater disposal.

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Numerous water treatment technologies are available today to address all of the shale production industry’s water management needs, including water quality, expanded water sourcing, water recycling, sustainable and cost-effective operations. Many of them are relatively unfamiliar to the oil and gas industry, including ultrafiltration (UF), reverse osmosis (RO), nanofiltration (NF), and ion exchange (IO), but these advanced water treatment technologies are widely used in other industries where water scarcity drives reuse and conservation.

Existing water treatment technologies not only make it possible to use the lowest quality source water available for fracking, but contribute to higher production at lower costs. For instance, Dow helped a shale producer in the western US achieve a 99.5 percent recovery rate in their flowback water treatment by converting them from traditional bag filters to the TEQUATIC™ PLUS self-cleaning fine particle filter system for removal of oily solids. Designed to facilitate more continuous injection into disposal wells and provide a cleaner water supply around the shale formation, this technology eliminated the need for frequent bag filter change-outs, reduced solid waste disposal, and enabled a cost-saving staff reduction.

DOW OPTIPORE™ polymeric adsorbent technology will allow for capture of residual hydrocarbons while protecting the RO system at Encana Oil and Gas’ Neptune Water Treatment Facility in Wyoming which is designed to desalinate produced water to “receiving body quality” – the same purity as mountain spring water. This allows Encana to minimize the use and cost of freshwater resources while minimizing the complexities of local wastewater disposal and the cost of onsite wastewater trucking.

Dow also collaborated with Omni Water Solutions in Texas to develop a mobile water treatment unit to effectively treat flowback and produced water at their Eagle Ford shale site. This system combines nanofiltration, ultrafiltration and reverse osmosis membrane technologies to reduce water hardness and boron levels, and to selectively remove ions – such as calcium, magnesium and sulfate. Omni is now able to reuse the high-salinity produced water

that would otherwise interfere with fluid and formation chemistries, and reduce the use of freshwater resources in a state experiencing severe drought conditions.

There are many other examples of utilizing available water treatment technology to improve production while reducing costs and environmental impact.

Dow believes that the most sustainable hydraulic fracturing process – environmentally and economically – is a cost-effective, closed loop system where none of the materials, including water, are ever exposed to people or the environment. Dow has a wide range of advanced chemistry, bacterial, and technology solutions for water treatment to make this possible – helping operators improve shale oil and gas recovery while minimizing cost and environmental impact throughout the hydraulic fracturing process.

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Working Toward a Sustainable Energy Future As the global population continues to grow and the world gradually transitions to a sustainable, increasingly lower-carbon energy future, balancing the need for clean water and energy will remain a top priority for operators, regulators, and Dow. Experts agree that we will continue to rely on hydrocarbon fuels for many more decades, so Dow’s goal is to strengthen every link in the hydrocarbon value chain, continually breaking ground to help optimize supply, improve efficiencies and manage emissions.

Whether customers are looking to maximize oilfield production, improve refinery or gas processing operations, optimize water management or reduce their carbon footprint, Dow will always be a trusted collaborator for innovation. Dow’s mission is to be a game-changing partner dedicated to fueling innovations that create new opportunities and provide solutions for the most compelling challenges the oil and gas industry is facing now, and in the future.

The company’s approach toward a sustainable energy future is elemental. Dow harnesses the power of the periodic table and the human element to build bridges between possibilities and progress at the intersection of chemistry, biology and physics.

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News

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News

Glacier Energy Services appoints new heat transfer division MD

ENERGY sector service group Glacier Energy Services today confirms the appointment of highly experienced oil and gas leader Jim McAleese as managing director of its newly-formed heat transfer division.

Mr McAleese, 51, will lead Glacier’s heat transfer repair and refurbishment services business, which was augmented with the acquisition of MSL Heat Transfer in late September, complementing existing group company Ross Offshore.

The appointment follows Glacier’s recent restructure to focus on its companies’ core capabilities delivering specialist services for energy infrastructure onsite in any global location, and at its workshops across the UK and in South East Asia.

In addition to heat transfer services, Glacier also provides onsite machining through Roberts Pipeline Machining and Site Machining Services; non-destructive testing (NDT), provided by Professional Testing Services; and weld overlay for pressure control equipment from Wellclad.

Scott Martin, executive chairman of Glacier Energy Services, says: “Jim is a well-known name in energy with an outstanding track record managing major international work portfolios and securing high-value new business, he is a superb acquisition for the group.

“His substantial experience, from engineer to senior executive at the head of largescale global companies, is an asset as we work hard to achieve our growth plans – he knows what it takes to secure increased turnover and improve operational and safety performance, while managing a highly skilled, dynamic workforce.”

Before joining Glacier, Jim McAleese, had a lengthy career with Alderley Systems Ltd, most recently as managing director, with responsibility for leading company activities across the international energy sector.

A chartered engineer and member of the Institute of Measurement and Control, he also led business development activity at Alderley, securing new business valued in excess of £20m.

Glacier Energy Services, formed in 2011, has a staff of 225, with group turnover for the financial year 2014 expected to exceed £30million. Its businesses operate from industrial premises in Aberdeen, Glasgow, Dalgety Bay and Methil in Fife, Newcastle and Singapore.

The group supports operators and service companies on projects from the commissioning phase to full in-operations lifecycle of oil and gas platforms and vessels, windfarms and infrastructure in the energy and petrochemical industries.

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“To win an award of this prestige in competition with some of the most successful and innovative businesses in the United Kingdom is hugely satisfying.

We have assembled a truly remarkable group of the most capable people in our industry and ROVOP has been successful because of their tremendous commitment.

This award is about our business and is recognition of their talent and efforts.”

On October 2nd the managing director of rapidly growing subsea specialist ROVOP received prestigious industry recognition after being named as the UK’s EY Entrepreneur of the Year 2014 for international business growth.

Judges singled out Steven Gray from a shortlist of the nation’s most successful and innovative business leaders, for his outstanding achievement in building an organisation that has experienced exceptional global growth since its inception in 2011. The judges remarked that “Steven maximised his background in law and banking to become a true entrepreneur.”

Turnover at ROVOP has rocketed to a current rate of £25 million, with significant expansion still to come on the back of new contract wins, while the company has surpassed its goal of increasing its team to more than 130 people and continuing to attract new talent.

ROVOP, which is headquartered in Westhill, Aberdeenshire, is an independent company dedicated to providing remotely operated vehicles (ROVs) and services to the oil and gas and offshore renewables industries.

Mr Gray said: “We set out to provide the most capable and modern fleet, combined with the best personnel and highest quality of service, and have found it to be an ethos the energy industry has responded to. Demand has grown consistently and the high level of repeat business we have won makes us believe we are on the right track. We have established a strong reputation with some of the world’s leading energy companies and customers ask us to apply the same high standards around the world, more than 80% of our work is now in international markets and we have completed projects in 14 countries.

Jim Bishop, EY Scotland senior partner, said: “This is the second year in a row that Scots have won more individual Entrepreneur Of The Year categories than any other region of the UK, highlighting the depth of Scottish entrepreneurial talent and the strength of our programme north of the Border.

“In a year when Scotland-based events have dominated headlines, it’s satisfying to see Scots recognised at UK level for their entrepreneurial qualities and not just their politics or ability to host world-class events.”

Since being founded, ROVOP has fast evolved into an industry-leading player and gone on to become an approved supplier to some of the world’s largest oil and gas and subsea construction companies.

In addition, the company has invested £35 million ($58 million) into its continuallyexpanding fleet of ROVS and also established its own ROV Academy which has been developed to ensure a supply of the most competent offshore personnel, predominantly pilot-technicians.

This latest accolade mirrors the success ROVOP has already enjoyed after being awarded the 2013 SPE Offshore Achievement award for Great Small Company and New Enterprise at Subsea UK’s 2014 awards ceremony.

The EY awards ceremony was held at The Brewery in the City of London.

More information about ROVOP can be found at: www.rovop.com

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ROVOP leader named UK Entrepreneur of the Year for global growth

Mr Gray reached the UK final after being selected as one of the EY regional winners for Scotland in June. With a background in law, financing and investing, he took advantage of world-class engineering skills in Aberdeen, innovative use of financing methods and created an open company culture to build an exceptional business.

ROVOP was one of two Aberdeenshire businesses that won an award.

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Chevron Announces Sale and Joint Venture Partnership for Duvernay Shale Assets in Canada with KUFPEC Chevron Corporation (NYSE: CVX) has announced that its indirect, whollyowned subsidiary, Chevron Canada Limited, has reached agreement to sell a 30 percent interest in its Duvernay shale play to Kuwait Foreign Petroleum Exploration Company’s wholly-owned subsidiary, KUFPEC Canada Inc., for $1.5 billion. The total purchase price includes cash paid at closing as well as a carry of a portion of Chevron Canada’s share of the joint venture’s future capital costs.

The Duvernay is located in west-central Alberta, and is believed to be among the most promising shale opportunities in North America.

Chevron Corporation (NYSE: CVX) announced that its Bangladesh subsidiary has commenced natural gas production from the Bibiyana Expansion Project in the northeastern part of the country.

The project included an expansion of the existing gas plant to process increased natural gas volumes from the Bibiyana Field, additional development wells and an enhanced gas liquids recovery unit.

The project is expected to boost Chevronoperated natural gas production capacity in Bangladesh by more than 300 million cubic feet per day to 1.4 billion cubic feet per day. In addition, the project is expected to increase the company-operated natural gas liquids production capacity by 4,000 barrels per day to 9,000 barrels per day.

Chevron’s Bangladesh subsidiary has a 99 percent working interest in Bibiyana.

“The Bibiyana expansion represents Chevron’s commitment to developing new resources to meet energy demand in Asia,” said Jay Johnson, senior vice president, Upstream, Chevron Corporation. “The expansion is one of a slate of projects across the region that will deliver on Chevron’s strategy to grow profitably in core areas.”

Melody Meyer, president, Chevron Asia Pacific Exploration and Production, said, “As the leading international investor in Bangladesh, Chevron values its partnership with the people of Bangladesh in support of the nation’s energy security and long-term economic development.

The Bibiyana Expansion Project is a further example of our commitment to invest for the long term and create value for our partners and the communities that we serve.”

Chevron is one of the world’s leading integrated energy companies, with subsidiaries that conduct business worldwide. The company is involved in virtually every facet of the energy industry. Chevron explores for, produces and transports crude oil and natural gas; refines, markets and distributes transportation fuels and lubricants; manufactures and sells petrochemical products; generates power and produces geothermal energy; and develops the energy resources of the future, including biofuels. Chevron is based in San Ramon, Calif. More information about Chevron is available at www.chevron.com.

The agreement creates a partnership for appraisal and development of liquidsrich shale resources in approximately 330,000 net acres in the Kaybob area of the Duvernay.

“This sale demonstrates our focus on strategically managing our portfolio to maximize the value of our global upstream businesses and is consistent with our partnership strategy,” said Jay Johnson, senior vice president, Upstream, Chevron Corporation. “The transaction provides us an expanded relationship with a valued partner. It also recognizes the outstanding asset base we have assembled.”

Following the closing of the transaction, Chevron Canada will hold a 70 percent interest in the joint venture Duvernay acreage and will remain the operator.

The transaction is expected to close in November 2014.

“We remain encouraged by the early results of our exploration program and view the Kaybob Duvernay as an exciting growth opportunity for the company,” said Jeff Shellebarger, president of Chevron North America Exploration and Production Company.

Chevron Canada has drilled 16 wells since beginning its exploration program, with initial well production rates of up to 7.5 million cubic feet of natural gas and 1,300 barrels of condensate per day. A pad drilling program recently commenced which is intended to further evaluate and optimize reservoir performance as well as reduce execution costs and cycle time.

News

Chevron Announces First Gas From Bangladesh Bibiyana Expansion Project

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News The Downstream segment reported underlying pre-tax replacement cost profit for the quarter of $1.5 billion compared with $0.7 billion a year earlier. The improvement was driven by a stronger refining environment as well as an increased contribution from supply and trading activities.

News

BP Reports Third Quarter 2014 Results BP reported its financial results for the third quarter of 2014. Underlying replacement cost profit1 for the quarter was $3.0 billion, compared with $3.7 billion for the same period in 2013.

Operating cash flow for the quarter was $9.4 billion, compared with $6.3 billion in 3Q 2013. Total operating cash flow for the first nine months of 2014 was $25.5 billion.

“BP’s operational momentum continues to deliver results,” said Bob Dudley, BP Group Chief Executive. “Growing underlying production of oil and gas and a good downstream performance generated strong cash flow in the third quarter, despite lower oil prices. This keeps us well on track to hit our targets for 2014.”

Reflecting confidence in delivering its 2014 operating cash flow targets and the robustness of its financial framework in a weaker oil price environment, BP announced a quarterly dividend of 10 cents per ordinary share, a 5.3% year-onyear increase. It is expected to be paid in December.

BP has continued its programme of share buy-backs and $10 billion has now been used to buy back shares for cancellation since March 2013. Divestments with a cumulative value of $4 billion have now been agreed towards a total of $10 billion expected by the end of 2015.

Organic capital expenditure in the first nine months of 2014 was $16.3 billion and BP now expects organic capital expenditure for the full year to be around $23 billion, compared with previous guidance of $24-25 billion.

At the end of the third quarter BP’s net debt was equivalent to a gearing level of 15.0%, within the company’s target range of 10% to 20%.

“We are maintaining our strong financial framework, with both a conservative level of gearing and a strictly disciplined approach to investment,” commented Brian Gilvary, BP Chief Financial Officer.

“This provides resilience through periods of oil market volatility.”

BP’s Upstream segment reported underlying pre-tax replacement cost profit of $3.9 billion for 3Q 2014 compared with $4.4 billion a year earlier. This result reflected the negative impacts of lower oil prices, partly offset by higher gas prices and increased production from key higher-margin regions.

BP’s total reported oil and gas production for the quarter averaged 3.1 million barrels of oil equivalent a day (mmboed).

Excluding Russia, underlying oil and gas production2 grew strongly, by 4.1% compared with the third quarter of 2013.

Reported production excluding Russia was 2.1 mmboed, 2.7% lower than the third quarter of 2013 due primarily to the expiry of an Abu Dhabi concession in January 2014.

BP reported underlying net income from Rosneft for the quarter of $110 million compared with $808 million a year earlier3. The depreciation of the rouble against the dollar over the period had a significant impact on the result, together with lower Urals oil prices and associated duty tax lag effects.

In exploration, three oil discoveries have been made since mid-year: Vorlich in the central UK North Sea, Xerelete in Brazil’s Campos basin, and Guadalupe in the deepwater US Gulf of Mexico.

“These three discoveries come after successful wells in Angola and Egypt earlier in the year. This builds on 2013, our best year for exploration drilling in a decade, and demonstrates our success in rebuilding the momentum of our exploration programme,” said Dudley.

The start-up of the Kinnoull project in the UK North Sea is now in progress – the sixth major upstream project start-up in 2014. The Sunrise project in Canada is also scheduled to begin operations before the end of the year. In addition, production at the Rhum gas field in the UK North Sea has recommenced following implementation of a temporary management scheme with the UK government.

The total cumulative pre-tax charge for the Gulf of Mexico oil spill remained at $43 billion at the end of the quarter4.

In September 2014, the district court in New Orleans ruled that, under the US Clean Water Act (CWA), the discharge of oil was the result of gross negligence and wilful misconduct by BP Exploration & Production Inc (BPXP) and that BPXP is therefore subject to enhanced civil penalties. BP intends to appeal this ruling5.

During the quarter, increased costs for claims administration, natural resource damage assessment and business economic loss claims eliminated the remaining unallocated headroom in the $20 billion trust. Subsequent costs over and above that provided within the trust will be charged to the income statement; $25 million was charged in the third quarter. The aggregate remaining cash balance in the trust and qualified settlement funds at the end of the quarter was $6.0 billion.

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Joint Shipping Initiative funds new phase of anti-piracy project in Somalia The Joint Shipping Initiative - made up of Shell, BP, Maersk, Stena and Japanese shipping companies NYK, MOL and “K” Line – today announced it has given $1.5 million of additional funds to a United Nations Development Programme (UNDP) project to improve the lives of Somalis and security for seafarers.

The UNDP’s “Alternative Livelihoods to Piracy in Puntland and Central Regions of Somalia” project aims to reduce piracy off the coast of east Africa through local economic development, job creation, training, and business development grants on-shore in one of the world’s poorest countries.

“Development projects that provide an alternative livelihood to would-be pirates are a vital element of the long-term solution to piracy,” Dr Grahaeme

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Henderson, Vice President of Shell Shipping & Maritime, said. “We have been very encouraged by progress so far and look forward to positive results from this new phase of work.”

A lack of jobs and legitimate business opportunities for young people helps Somali pirate leaders to attract recruits for attacks on merchant shipping that cost the international community billions of dollars a year.

By offering alternative livelihood options to these youth, UNDP and the Joint Shipping Initiative work to prevent the lure of piracy.

“Somalia has one of the world’s highest rates of youth unemployment. Nearly 67% of young people are unemployed.

To reverse this reality, we work with local authorities and community groups to identify sustainable solutions – such as infrastructure projects, livelihoods trainings, or reintegration projects – and tailor our support to match the need,” stated UNDP Somalia Country Director George Conway.

Initiated by Shell in 2013, the Joint Shipping Initiative’s first donation of $1 million helped expand the market building

in Adado – a town in central Somalia – creating hundreds of jobs for retailers and better sales options for farmers. It also helped improve vital infrastructure, including building a road to link the isolated Hafun peninsula with the rest of the country - a project that generated hundreds of temporary jobs. The road also helps expand opportunities for trade and business, increasing access to communities in the Hafun peninsula.

In addition, training courses in skills such as computing, plumbing, building and clothes-making have been set up elsewhere to help young Somalis find work, or set up businesses themselves with the help of small grants.

Today’s additional funding meets the Joint Shipping Initiative’s 2012 pledge to donate a total of $2.5 million to UNDP’s development efforts in Somalia. It will allow UNDP to start work in the towns of Alula and Bargal, near the tip of the Horn of Africa, and Balanbal in central Somalia.

“Piracy is a global problem that takes root in limited economic opportunities, high youth unemployment rates and poor infrastructure,” Jens Munch Lund-Nielsen, Head of Emerging Markets Projects in Group Sustainability, Maersk, said. “The problem requires a land-based solution.”

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“We are delighted to have reached this milestone with our partners,” said Andrew Brown, Shell Upstream International Director. “Gumusut-Kakap is our first deep-water development in Malaysia, and uses the best of Shell’s global technology and capabilities in deep water. The field is one of a series of substantial deep-water start-ups this year, driving returns and growth for shareholders.”

This floating platform is the latest addition to Shell’s strong portfolio of major deep-water projects. Assembling the vast structure, whose four decks total nearly 40,000 square metres, involved the world’s heaviest onshore lift. The project uses Shell Smart Fields® technology to carefully control production from the undersea wells to achieve greater efficiency. Oil is transported to the Sabah Oil and Gas Terminal onshore at Kimanis, Malaysia via a 200 km-long pipeline.

Shell starts oil production from Gumusut-Kakap deep-water platform in Malaysia Shell has started oil production from the Gumusut-Kakap floating platform off the coast of Malaysia, the latest in a series of Shell deep-water projects.

The Gumusut-Kakap field is located in waters up to 1,200 metres (3,900 feet) deep. The platform is expected to reach an annual peak oil production of around 135,000 barrels a day, once fully ramped up. With oil production now under way, work on the gas injection facilities is continuing with an expected start-up during 2015.

Shell Malaysia Chairman Iain Lo said: “Shell is pleased to be able to play an active role in developing the nation’s deepwater resources and deep-water service industry. Deep-water resources are critical to Malaysia’s long-term energy security.

The Gumusut-Kakap field is expected to contribute up to 25% of the country’s oil production.”

Gumusut-Kakap is the latest of more than 20 major deep-water projects that Shell has delivered around the globe. Shell began production from the Mars B development in the Gulf of Mexico through the Olympus platform in February this year.

In August it announced the start of oil production from the first well at the Bonga North West deep-water development off the Nigerian coast. In September, Shell announced the start of production from the Cardamom development, the latest deep-water breakthrough in the Gulf of Mexico which is a high-value addition to the Shell’s pioneering Auger tension-leg platform.

The Gumusut-Kakap project is a joint venture between Shell (33%, operator), ConocoPhillips Sabah (33%), PETRONAS Carigali (20%), Murphy Sabah Oil (14%).

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The project has allowed Shell to share deep-water expertise with Malaysian energy companies, assisting in the Malaysian government’s goal to create an offshore industry hub. The platform was built in Malaysia by Malaysian Marine and Heavy Engineering Sdn Bhd (MMHE).

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Schlumberger Introduces New Well Integrity Service

AMSTERDAM, October 28, 2014—Schlumberger announced today the release of Invizion Evaluation* well integrity service, which helps operators evaluate zonal isolation by using integrated drilling, cementing and well logging data.

“One key component in achieving zonal isolation is cementing, which can impact productivity, help prevent sustained casing pressure and annular flow, and mitigate loss of well control issues,” said Amerino Gatti, president, Well Services, Schlumberger.

“The Invizion Evaluation service combines all available data from open hole, cementing placement, and acoustic logs for cement evaluation in an integrated workflow. This service supports customer decision making during the well construction and completion phases to help ensure a robust cement barrier.”

The Invizion Evaluation service uses real-time and post-job data to help identify zonal isolation issues that could impact well integrity. To perform well, pad or field analysis, petrotechnical experts can evaluate drilling surface parameters, formation rock properties, cement barrier placement, and cased hole cement evaluation logs.

Field tested in a wide range of field locations, including offshore environments in the Gulf of Mexico and Alaska, unconventional wells in Colorado and the Eagle Ford Shale, the Invizion Evaluation service enabled customers to confirm that cement placement was achieved as planned.

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The service also allowed them to identify zonal isolation issues, understand the reasons the issues existed in the short and long term, and minimize the potential impact on well integrity.

In Alaska, the Invizion Evaluation service’s integrated workflow was used to help in job planning, and the Isolation Scanner* cement evaluation service was used to successfully save more than 15 hours in waiting-on-cement and operational costs. These services enabled the well to be logged 27 hours after the cement job instead of the typical 42 to 72 hours, helped the customer determine the quality of the cement bond, and confirmed that the cement had set.

Invizion Evaluation service is the first member of the Invizion* integrated zonal isolation services. For more information, visit www.slb.com/Invizion.

About Schlumberger Schlumberger is the world’s leading supplier of technology, integrated project management and information solutions to customers working in the oil and gas industry worldwide.

Employing approximately 126,000 people representing over 140 nationalities and working in more than 85 countries, Schlumberger provides the industry’s widest range of products and services from exploration through production.

Schlumberger Limited has principal offices in Paris, Houston, London and The Hague, and reported revenues from continuing operations of $45.27 billion in 2013. For more information, visit www. slb.com.

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Invizion Evaluation service provides E&P operators an increased level of well integrity assurance by enhancing cement evaluation techniques

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BP and CGG Agree to Develop Next-Generation Marine Seismic Source Technology Baker Hughes Implements New Policy of Full

Chemical Disclosure for Fracturing Operations

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Baker Hughes Incorporated (NYSE: BHI) announced that it has implemented a new policy of disclosing 100% of the chemistry contained within its hydraulic fracturing fluid systems, without the use of any trade secret designations.

The company announced in March of this year its plans to provide complete lists of all of its products and chemical constituents for all wells it fractures using its hydraulic fracturing fluid products, without detailing specific product formulations. In so doing, Baker Hughes hopes to increase public trust in the process of hydraulic fracturing, while still protecting the market-driven commercial innovation that has helped the company become a global industry leader.

“Introducing greater transparency about the chemicals used in the hydraulic fracturing process and protecting the ability to innovate are not conflicting goals,” said Derek Mathieson, Baker Hughes chief strategy officer. “The policy we are implementing today is consistent with our belief that we are partners in solving industry challenges, and that we have a responsibility to provide the public with the information they want and deserve. It simultaneously enables us to protect proprietary information that is critical to our growth.”

For each fracturing job the company performs on or after October 1, 2014, the policy mandates that Baker Hughes will disclose a single list of all of the chemical constituents of its products used, while also specifying their maximum concentrations.

Baker Hughes’ policy is fully compatible with the online national hydraulic fracturing chemical registry known as FracFocus. All of the company’s disclosure forms can be found at www.fracfocus.org.

Baker Hughes is a leading supplier of oilfield services, products, technology and systems to the worldwide oil and natural gas industry.

The company’s 60,000 employees today work in more than 80 countries helping customers find, evaluate, drill, produce, transport and process hydrocarbon resources. For more information on Baker Hughes, visit: www.bakerhughes.com.

Two global companies to collaborate on R&D to take offshore industry’s subsea imaging capability to the next level.

BP and CGG today announced an agreement for collaborative research and development in the field of new types of marine vibratory seismic sources. The agreement combines the companies’ research efforts and expertise to develop and deploy innovative seismic source technology, and builds on successful prototype trials.

Seismic surveys have for decades been the exploration industry’s key tool for identifying oil- and gas-bearing rocks below the seabed. And both BP and CGG recognize the significant potential for new vibratory seismic sources to improve technical performance, while maintaining a focus on environmental sensitivity.

“BP has an established track record of innovation and industry leadership in the area of seismic acquisition, which plays to our notable strengths in exploration and resource progression,” said Eric Green, Vice President Advanced Seismic Imaging Technology at BP. “This agreement highlights BP’s ongoing commitment to remaining at the forefront of this important field. We welcome this exciting opportunity to cooperate on novel marine source technology with CGG.” Thierry Brizard, Executive Vice President, Technology, CGG, said: “Historically, CGG has consistently taken the lead in the development and implementation of new technological advances for seismic acquisition. Recent examples are our BroadSeis-BroadSource technology for true broadband marine seismic imaging and our Sercel 508XT, which sets the new standard for onshore MegaCrew acquisition. We look forward to joining forces with BP to develop new seismic source technology that will have a profound impact on the future of the seismic industry.”

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Kuwait National Petroleum Company

“Integration and Excellence” Since its incorporation, the Kuwait National Petroleum Company (KNPC) has engaged in different activities within the oil industry. When it was established in 1960 KNPC was the only and first national company in a region where hydrocarbon resources were managed and exploited by foreign companies. The owners’ vision was a stimulating development and provided an exemplary experience in handling national resources. In its perspective KNPC came as a model for the indigenous potentials, to undertake management and exploitation of the oil resources which started to develop into a colossal source of income capable of sustaining the society welfare and financing its over all development.

www.ogsmag.com (KPC) was established as a state owned asset and all other oil companies in Kuwait, including KNPC, became KPC subsidiaries. One year later, after the establishment of KPC, the oil sector in Kuwait was restructured on sectorial basis. KNPC became responsible for the oil refining and gas liquefaction industry in addition to the marketing of petroleum products in Kuwait through a chain of filling stations, which reached its peak between 2005 and 2007, with 119 operating filling stations. In collaboration with KPC the company embarked on studies and plans to modernize the refining industry in Kuwait with a multi billion-dollar projects to revamp Mina AlAhmadi and Mina Abdullah Refineries.

By 1984 the Mina Al-Ahmadi Refinery Modernization Project (RMP) was completed and it was supplemented by the Further Upgrading Project (FUP) in 1986. The two projects practically created a modern new refinery with optimal configuration and advanced technology, and significantly increased the overall capacity of the plant. Two years later Mina Abdullah Refinery modernization project (MAB) was completed turning the old refinery into a state of the art plant with a sizable capacity increase. MAA-RMP and MAB-RMP led not only to capacity increase but also to products quality improvement.

In 1975 the State acquired full ownership of KNPC. At that time KNPC’s operations were highly integrated mainly relying upon its oil refinery in Shuaiba and the marketing of petroleum products from Al-Ahmadi Refinery, run at the time by Kuwait Oil Company KOC- in both Local and international markets. However, KNPC at that time was also managing a presence in Europe, the Far East and United States of America to handle the marketing of petroleum products from the Kuwait refineries. It even owned and operated a number of oil tankers to deliver petroleum products to customers all across the world.

In 1980 Kuwait Petroleum Corporation

On the domestic scene KNPC continued to build new filling stations in order to add more outlets for products marketing and to respond to the growing demand for gasoline and other fuels. However, KPC and KNPC put into effect the trend towards privatization and started in 2004 to transfer its Local Marketing assets, such as the lube oil plant and the petrol stations, to private companies. In 2004 the well-established Lube Oil Blending Plant in Shuaiba was sold to a private firm and in early 2005 the privatization process of 119 filling stations commenced with transferring the ownership of 40 filling stations to a shareholding private company. In early 2006 another batch of 40 filling stations was turned over to another shareholding company. The privatization process continued until the last filling station owned by KNPC, is passed to the private sector.

In the meantime the company gave special attention to its human resource by implementing a policy of steady growth of the national manpower and providing the company sites with highly qualified human resources. By the year 2009 the percentage

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of Kuwaitis in the total workforce of 5,235 employees was around 79.5%.

KEY REFINERIES Mina Abdullah refinery - the total area covered by its installations is 7,935,000 m2. The refinery was first built in 1958 by the American Independent Oil Company “AMINOIL”, during the rule of the late Sheik Abdullah Al-Salem Al-Sabah.

Back then it was a simple refinery that contained one crude oil distillation unit with a capacity of approximately 30,000 bpd. Following several expansion projects between 1962 and 1967 its refining capacity rose to approximately 145,000 bpd. The Mina Abdullah Refinery became a state owned property following a transition period, during which the refinery was managed by a national company under the name of “Wafra Oil Company”. Ownership of the refinery was transferred to KNPC in 1978.

Mina Al-Ahmadi Refinery (MAA) was built in 1949 as a simple refinery with a refining capacity not exceeding 25,000 bpd, to supply the local market with its gasoline, kerosene and diesel needs. The refinery is located 45 km to the South of Kuwait City on the Arabian Gulf and covers a total area of 10,534,000 m2.

Following the establishment of KPC and the restructuring of the oil sector, ownership of the refinery was passed from Kuwait Oil Company (KOC) to Kuwait National Petroleum Company (KNPC), which became responsible for the oil refining and gas liquefaction operations in Kuwait. In the early 1980’s as part of an overall plan to upgrade the refining industry and expand the refineries, work started on two ambitious projects to modernize Mina Al-Ahmadi Refinery, namely the MAA-Refinery Modernization Project (MAA-RMP) (which was completed in 1984) and the Further Upgrading Project MAA-FUP (which was commissioned in 1986). Within the framework of these two projects, 29 new units were built at this refinery, which has since become one of the world’s modern refineries in terms of both refining capacity, which exceeds 460,000 bpd and the advanced technology it employs.

Projects As an established player in the Middle Eastern marketplace, KNPC has been able to look at securing its future. Most recently it has undertaken two major projects, the Al Zour refinery project and the Clean Fuel project.

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CLEAN FUEL PROJECT (CFP) This is one of the strategic projects of Kuwait National Petroleum Company that aim to upgrade and expand the existing KNPC two refineries at Mina Abdulla and Mina Al-Ahmadi. The CFP will transform the two refineries into an integrated merchant refining complex that meets the diversified requirements of the world oil market. Carrying out the project will allow for maintained high safety and environment standards in line with KPC directions and total refining capacity of this complex after the CFP completion will go up to 800,000 barrels a day. The updated and sanctioned budget for CFP is KD 4,680 million and it is on target for completion in 2017.

AL-ZOUR REFINERY PROJECT (ZOR) The project is intended to build a grass root refinery in the Al-Zour area, south of Kuwait City, with a total capacity of 615,000 barrels per day. The refinery has a strategic goal of supplying low sulfur fuel (less than 1% compared to the current 4% sulfur fuel) to local power plants.

This will significantly reduce pollutant emissions and in that sense it constitutes a special importance to the environment. Al-Zour Refinery, which will be one of the largest oil refining plants worldwide, will fulfill the downstream strategy of Kuwait Petroleum Corporation. In addition to its domestic benefits as the prime supplier of feedstock to the power plants, Al-Zour Refinery will enhance competitiveness of Kuwait petroleum products on the world markets on the account of its ability to meet the stringent requirements of those markets.

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BHP Billiton

A Leading Global Resources Company

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BHP Billiton is a leading global resources company, formed from a merger between BHP and Billiton. From two small mining companies founded in the mid-1800s, BHP Billiton is now a world leader in the diversified resources industry. The company is among the world’s largest producers of major commodities including, aluminium, coal, copper, iron ore, manganese, nickel, silver and uranium, and have substantial interests in oil and gas. An unrivalled portfolio of high quality growth opportunities will ensure BHP Billiton continues to meet the changing needs of its customers and the resources demand of emerging economies at every stage of their growth. The diversification of the BHP Billiton portfolio continues to be its defining attribute.

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History Billiton’s roots trace back to 1851 and a tin mine on a little known island in Indonesia, Billiton (Belitung) island. Billiton became a global leader in the metals and mining sector and a major producer of aluminium and alumina, chrome and manganese ores and alloys, steaming coal, nickel and titanium minerals.

Billiton also developed a substantial and growing copper portfolio.

Broken Hill Proprietary’s rich history began in a silver, lead and zinc mine in Broken Hill, Australia.

Incorporated in 1885, BHP engaged in the discovery, development, production and marketing of iron ore, copper, oil and gas, diamonds, silver, lead, zinc and a range of other natural resources. BHP was also a market leader in value-added flat steel products.

BHP and Billiton merged in June 2001, becoming one of the world’s largest diversified resources businesses that is today among the world’s largest producers of major commodities, including aluminium, coal, copper, iron ore, manganese, nickel, silver and uranium, and with substantial interests in oil and gas. In 2010, BHP Billiton celebrated its 150th anniversary and three significant milestones: Billiton’s establishment on 28 October 1860, BHP’s incorporation on 13 August 1885 and BHP Billiton’s listing on the Australian and London Stock Exchanges on 29 June 2001.

Business Areas BHP Billiton’s’ aluminium business has a portfolio of assets in three stages of the primary aluminium value chain: mining bauxite, refining bauxite into alumina and smelting alumina into aluminium metal.

It is one of the world’s largest integrated producers with operations in South America, Southern Africa and Australia.

Aluminium is a widely used non-ferrous metal with demand driven by end use consumption in transportation, packaging, construction and household items.

Its nickel business is one of the world’s largest nickel miners, the fifth largest refined nickel producer and a global supplier of nickel to the stainless steel industry.

BHP Billiton has two producing assets located in Australia and Colombia. Austenitic stainless steel, or nickel-containing stainless steel, promotes a more stable and ductile structure that contributes to corrosion resistance. This product is instrumental to many industries including architecture, transport, aerospace, medical and heavy industries as well as chemical processing and energy applications.

Nickel is also an essential element in many non-stainless steel applications like specialty alloys, foundry, chemicals and refractory material industries.

The manganese business has two producing assets located in Australia and South Africa and is a world leader in the seaborne supply of manganese ore and a global producer of manganese alloy.

Manganese is an indispensable element in the manufacturing of steel, which in turn is an essential material in many industries including construction and transportation. Its use in the steel making process results in increased strength, resistance and machinability.

BHP Billiton’s globally diversified coal business produces thermal coal primarily for use in the electric power generation industry and high quality hard coking coal

for use in the international and domestic steel industry. With operations strategically located in areas with seaborne access, the business delivers logistical advantages to its customers.

BHP Billiton has access to dedicated deep-water ports allowing the use of large capacity vessels to further build on regional logistic advantages. There are eight thermal coal operations located in South Africa, Australia, the United States and South America. In addition to seaborne supply into the Atlantic and Pacific markets, BHP Billiton services domestic markets in South Africa, Australia and the United States.

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Metallurgical coal has a total of eleven operations and a further two green-fields mines under construction in Australia.

has the flexibility to continually expand BHP Billiton’s production capacity in line with customer needs.

These assets produce high quality hard coking coal, which is an essential raw material in the production of steel. This high quality hard coking coal is produced from low cost asset bases in Queensland (predominantly open cut mines owned in an alliance with Mitsubishi Development Pty Ltd and Mitsui) and New South Wales (100 per cent underground operations). With long life reserves, a strong portfolio of undeveloped resources and key infrastructure, the Coal business

BHP Billiton’s copper business has an excellent portfolio of mining operations with substantial growth opportunities and a number of expansion opportunities — both greenfield (new sites) and brownfield (developments on existing sites). This is allowing the company to expand production significantly through various projects. With a portfolio of large, low-cost mining operations — including the Escondida mine in Chile which is the world’s largest single producer

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of copper — the aim is to become the pre-eminent supplier in copper through capacity expansions, reliable supply and innovative solutions. The operations also produce uranium oxide concentrate, lead concentrates and zinc concentrates, and provide base metal concentrates to custom smelters and copper cathodes to rod and brass mills and casting plants. BHP Billiton is also focused on exploration. Its greenfield activities allow exploration of some of the most geologically prospective terrains across a wide array of countries and operating environments. Exploration activities include opportunity identification, application for and

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acquisition of mineral title, early reconnaissance operations to multimillion-dollar delineation drilling programs.

BHP Billiton Iron Ore is one of the world’s leading iron ore producers with operations in Australia and Brazil, selling lump and fine product from Australia and iron ore pellets from its Samarco operation in Brazil.

Principal iron ore operations are based in the Pilbara region of northern Western Australia. The operation comprises a complex integrated system of seven inland mining operations, more than 1,000km of rail, stockyards and two separate port facilities located in Port Hedland. These operations are owned through a number of Joint Venture arrangements. BHP Billiton Iron Ore is a 50:50 joint venture partner with Vale at the Samarco operations in Brazil. Iron ore is a major component in many modern office towers, including iconic structures around the world. It is also used extensively in motor vehicles, washing machines, refrigerators, ovens and other white goods. In pursuing ongoing growth plans, BHP Billiton Iron Ore is committed to working with its local communities to support sustainable development in the region and ensure their needs are incorporated into the company’s expansion plans.

working interest with a bias for operatorship. It also holds interests in exploration blocks, exploring for significant upstream opportunities in proven basins and promising prospects around the world using the latest seismic and geophysical technology to locate new resources.

BHP Billiton’s potash activities are aimed at potash project development. Its interest in potash is via development projects largely within the Canadian province of Saskatchewan. Potash is a globally traded commodity primarily used as a fertiliser. BHP Billiton has exploration rights to over 14,500 square kilometres of highly prospective ground in the Saskatchewan potash basin.

The Jansen Project, located 140 kilometres east of Saskatoon, Saskatchewan, is its most advanced project and is in feasibility study stage.

Sustainable Communities

This month, in response to the widespread devastation caused by the Ebola outbreak in West Africa, BHP Billiton Sustainable Communities has donated US$400,000 to the Pooled World Health Organisation (WHO) Ebola Response fund. The contribution from BHP Billiton will provide immediate actions to support affected countries and will provide interventions in neighbouring BHP Billiton Petroleum has at risk countries until December exploration, development, 2014. BHP Billiton has worked in production and marketing activities West Africa for a number of years in more than a dozen countries through its iron ore exploration around the globe, with a significant assets. Business Director West position in the deep water Gulf of Africa Iron Ore, Graham Reynolds, Mexico, onshore US and Australia. said: “The West Africa region is Petroleum also operates assets in desperate need of international in the United States, Australia, assistance to contain Ebola. It United Kingdom, Trinidad and is both a direct and indirect Tobago and Pakistan. Its oil and humanitarian disaster impacting on gas strategy is to focus on material every person living in the affected opportunities, at high countries including our employees

and contractors past and present.”

BHP Billiton Sustainable Communities is a charity established by BHP Billiton as part of its community investment program. Most projects supported

by BHP Billiton Sustainable Communities are multi-year projects and they predominantly focus on building capacity of individuals and institutions, ensuring the programs will leave

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a lasting positive legacy after completion.

Striving For Excellence BHP Billiton never takes its performance for granted. It continues daily to strive to safely operate all of its assets at capacity and continue to identify those resources that it will leave to the next generation of BHP Billiton leaders.

BHP Billiton is committed to the health and safety of its people, the environment and the communities in which it operates. The long-term nature of its operations allows it to establish long lasting relationships with the host communities where it works together to make a positive contribution to the lives of people who live near its operations and to society in general.

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VersaDev Established in 2000 in Adelaide, South Australia, VersaDev provides businesses with turnkey off the shelf and bespoke technology solutions. At start-up the company worked on solutions for local government. In 2002 VersaDev were asked to become a Microsoft certified partner, a move that greatly increased the company’s visibility in the marketplace. VersaDev strengths are its staff and their ability to quickly respond to its clients’ needs. The business has been built through enterprise level managed solutions, and VersaDev’s close partnerships with its client base.

BHP Billiton is the world’s largest diversified resources company. It is also VersaDev’s biggest client in terms of software usage by processing volume. The partnership began with BHP’s Shared Services Centre in Adelaide.

BHP wanted a fast turnaround for their software needs and VersaDev were able to provide a range of solutions.

The business critical nature and deliverable timing of their projects, with implications for business process improvements and the need for access for independent auditing, required a solution which was flexible, easily manageable yet needing to be delivered rapidly. Based on the Microsoft .NET Framework and delivered through the web browser, VersaDev systems provide BHP Billiton personnel with the ability to use a solution which is real time, eliminate labour intensive manual processing, utilise user security based workflow and sign-off and report effectively on outcomes.

VersaDev also provides BHP Billiton with versaSRS, a flexible and scalable solution for managing service request processes. As a result, BHP Billiton has adopted versaSRS for managing service requests for both Human Resources, Supply & Financial Services to effectively manage required actions and requests internally throughout the organisation globally.

The nature of BHP Billiton’s business is continual improvement and they have people in the business who are dedicated to this, so the fit with VersaDev was good. As time as gone on and the partnership has grown this ethos remains within BHP Billiton right across the globe. Most recently VersaDev has been working with BHP Billiton at their headquarters in Saskatoon, Canada, to deliver a stakeholder community communications system that provides transparency across the various projects in the region. It is a reflection of BHP Billiton’s ongoing ethos that they are keen to be highly visible and accountable within the local community.

The partnership with BHP Billiton has been a good local story for a local Australian firm.

10+ Years Experience In-House Consultants In-House Developers On Budget, On Time

business transformation software "It is the scalability of their solutions that impresses us.

"Whether it is supporting our HR department globally by

Delivering REAL Solutions

managing 20,000 cases on average per month, or it is

On-Premise or in The Cloud

their solutions cater for both reqirements.

Mic Microsoft Silver Partner for 10+ years Global 24/7 support to clients such as BHP Billiton

supporting our Marketing team with 20 cases per month,

"VersaDev are big enough to deliver and small enough to care."

versaSRS Full Circle Business Improvement

Streamlining Finance

versaSRS.com

RecWise.com

Drive Business Process

Satisfy Audit

Centralise Communications

Meet ROI

Create Collaboration

Deliver Results

Manage Workflows

Manage Performance

Ensure Continuity

Automate Reconciliations

Measure Outcomes

Track Aged Items

Ph +61 (8) 8463 1914

sales@versadev.com

48

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SCHÜNEMANN FILTERS: THE NEW F480

A NEW GIANT The new F480: the right choice wherever filter performance is a question of time, water volume, and cost. With volume flow up to 45,000 m³/h and diameters up to 2,000 mm, it treats fluids (e.g., salt water) for a great variety of processes. As a result, it protects facilities to an extensive degree from dirt and debris – and at the same time specifically minimizes operational and maintenance costs.

In addition, the F480 requires extremely little space – to save time, money, and energy. It therefore represents a small wonder – and it’s no wonder that many and various industries have already learned to place great trust in it.

We’d be glad to give you more details on the F480 and its tremendous possibilities under www.sab-bremen.de.

GEORG SCHÜNEMANN GMBH Buntentorsdeich 1 · 28201 Bremen · Germany Tel. +49 (0)421-5 59 09-0 · Fax +49 (0)421-5 59 09-40 info@sab-bremen.de · www.sab-bremen.de

Meet · Deliver · Succeed

VROON provides a diverse range of services and solutions for key offshore-support needs, including platform supply, emergency response and rescue, anchor handling and subsea support.

Our versatile fleet of more than 100 vessels follows a rigorous maintenance programme, which together with ongoing orders for new builds, ensures our continued commitment to providing services that are safe, reliable and cost effective.

We have the fleet to meet your needs, the people to deliver and the determination to succeed.

For more information visit www.vroonoffshore.com

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