OGI Autumn 2014 by Emery Hill Media Ltd

Autumn 2014

Business Information Industry Solutions

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www.oilandgasinnovation.co.uk

Autumn 2014

FROM THE EDITOR

CEO Matthew Patten

In the Face of Crisis with Europe Over the Annexation of Crimea and the Separatist Insurgency in Eastern Ukraine, Russia’s Economy is Increasingly Dependent on Gas Exports, in the Other Direction.

Managing Editor Simon Milliere Publishing Director Edward Findlay edward@oilandgasinnovation.co.uk Commercial Director Nicholas Parker nparker@oilandgasinnovation.co.uk Marketing Manager and Creative Anja Istenič Technical Director and Website Valters Skrupskis Office Assistants Janet Elseberg admin@oilandgasinnovation.co.uk Mylene Daugan mylene@oilandgasinnovation.co.uk Contributing Journalist Emma Patten Business Development Executives Dayanch Ylyasov Paolo Traina Smahane Makrini Market Researchers Hedlyne Grenot Amara Waqar Sarah Ahmed Jesse Wiafe Emery Hill Media 37th Floor 1 Canada Square London E14 5AA Tel: +44 203 239 1581

In a speech by Alexey Miller about global gas industry outlooks and problems at 4th St. Petersburg International Gas Forum recently, some very interesting proposals came up. For those who don’t know, Mr Miller is of course the Deputy Chairman of the Board of Directors and Chairman of the Management Committee of Russian energy company Gazprom, Russia’s largest company and the world’s biggest natural gas producer. Since problems in Ukraine escalated in March, and Russia decided to intervene, the West has tried to propose “crippling” sanctions on many aspects of the Russian economy hoping that would both de-escalate the situation and prevent Russia from annexing anymore territory from sovereign Ukraine. One of the most difficult selling points of the sanction package to American allies is of course European import restrictions. It’s no small measure that most of Central and Eastern Europe’s gas imports come from the Russian Federation. Slovakia, Poland, Hungary, Finland, Greece, Austria and the Czech Republic each import at least 70% of their gas imports from Russia. Even Germany gets 39% of its gas from Russia. Possibly most important is Ukraine, who imports 77% of its gas from its neighbour. The expectation was that this part of the sanction package would not materialize and even Vladimir Putin himself said he did not expect Europe to decide to shut off the heat on the continent before the coming Winter. The argument coming from the Russian government was that Europe cannot slap heavy economic sanctions on the federation. This assertion would seem accurate. The Europeans cannot afford to risk having their houses not heated, or a major disruption in their gas supplies, or even a massive price increase in their heating bills. Russia holds a very strong hand here in dealing with this geopolitical crisis and that should have played well into the decision to annex The Crimea. In the end, it looks like Russia will repatriate the peninsula with relatively few immediate consequences because of its stranglehold on the European gas market. But the downing of Malaysia Flight 17, packed with Dutch citizens changed the landscape of potential European involvement in the sanctions. And with sanctions likely to go ahead, who is Russia and Gazprom to sell their gas too? On May 21st 2014 Russia signed a 30 year gas agreement with China. Shortly after his speech 4th St. Petersburg International Gas Forum, A Technical Agreement was signed by Alexey Miller, Chairman of the Gazprom Management Committee and Wang Dongjin, Vice President of CNPC in the House of the Russian Government in Moscow. It is a supplement to the Purchase and Sale Agreement on natural gas supplies via the eastern route. The document was inked in the presence of Dmitry Medvedev, Russia’s Prime Minister and Li Keqiang, Premier of China’s State Council. The Technical Agreement defines basic parameters of design, construction and operation of the Power of Siberia gas trunkline’s cross-border section. In addition, the document contains the main technical and technological features of conveying gas from seller to buyer. “As of today, all the necessary documents on gas supplies to China have been signed, including the Intergovernmental Agreement. The construction of Power of Siberia is in full swing. We have a particular plan and specific deadlines to be met without fail,” said Alexey Miller. Russia has turned East. Please Enjoy The Autumn 2014 Edition of Oil and Gas Technology. Yours Sincerely,

CONTENTS COVER STORIES & SPECIALS Heavy Lift & Ropes

Oil & Gas Innovationâ&#x20AC;&#x2122;s Emma Patten presents a comprehensive Interview with rope and wire professionals the Hendrik Veder Group and their heavy lift specialist, Hans Coenen. We also look at the SylWin alpha platform project.

Metering on FPSOs

Ms Patten also interviews Energy Project Solutions, who specialize in the design, production & implementation of flow measurement solutions which are increasingly being used offshore on floating platform, storage and offloading units.

Exxon: The Role of Lubricants

OGI contributor ExxonMobil helps explain to the readers how Advanced lubricants and greases help mitigate potential injury risks and simultaneously increase overall productivity for owners and operators in the oil and gas sector.

INDUSTRY NEWS Europe

North America Brazil

23 MENA 24 Africa 25 Russia and CIS 27 Asia Pacfic

EXPLORATION & PRODUCTION The Importance of Rig Inspections

An interview with Aberdeen Drilling Consultantsâ&#x20AC;&#x2122; Jason McGill on how rig inspections can can be done thoroughly, while also minimizing downtime.

Modern Engineering Methods for Oil Wells

Engineering consultants Engenya GmbH explain advances in technology which enable the user to reach deeper and deeper reservoirs.

“A definitive congress & exhibition for the industry and this year the participation list seems to be even more expansive. As a regionally strategic port that's about to triple its capacity for liquid storage we're delighted to be a part of this year's show.”

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CONTENTS EXPLORATION & PRODUCTION Offshore Vessels with the Newest Technologies

Europe Marine Control is a system integrator who designs, produces and delivers turnkey complete electrical installations and equipment (drive systems) for offshore vessels.

Project Management is Key

Ms Patten interviews Jonny Olsen, CEO of Nordhagen Management AS, which specializes in implementing software based project management solutions which help EPC contractors, operators and shipbuilders manage major projects and keep on time and budget.

MIDSTREAM & PIPELINES Automating Your Pipe-Yard Inventory Management

Software solutions like Tallys and TallyWizard are quickly becoming the standard for inventory tracking and management among leading companies in Canadian oilfields.

China Orders Oil Firms to Fix Faulty Pipelines

Preventing Unexpected Failure of Equipment

Unexpected failure of equipment is a problem in any major industry, often resulting in costly delays and downtime. Surface finishing techniques are proven to extend the life of components and ensure optimum operating performance and should be considered explains, Curtiss-Wright Surface Technologies.

MORE Processing

Total Relies on High Performance Computing

Upcoming Events

Key oil and gas events from around the globe.

Heavy Lift & Ropes.

In this special report Oil and Gas Innovation has an exclusive interview with the Hendrik Veder Group about their heavy lift wire and rope solutions to the offshore, marine, oil and gas industry. Plus we take a quick look at a Dutch amalgamation of companies who, earlier this year, installed a massive â&#x20AC;&#x153;power socket at seaâ&#x20AC;? in an unprecedented offshore heavy lift operation.

By Emma Patten

Installation of the Largest Transformer at Sea: Excellent Example of Holland’s Glory

utch offshore companies realised a unique operation in the North Sea. Under the direction of Seaway Heavy Lifting, one of the world’s largest converter platforms a ‘power socket at sea’ is installed to the west of Sylt, the East Frisian Island. Siemens built the SylWin alpha platform. It is so large and heavy that the ingenious ‘float over method’ has been used to lift it from a pontoon onto the already installed ‘jacket’ (the base of the platform). This approach has been used successfully in the Gulf of Mexico and in the Far East, but is the first time that a platform as large as SylW in alpha was installed using the method in the North Sea. Siemens commissioned Seaway Heavy Lifting (based in Zoetermeer, the Netherlands) to perform the unusual operation that in turn called in the assistance

of maritime service providers Dockwise and Mammoet. The 14,000Mt SylWin alpha platform was transported on a pontoon that has been positioned in between the jacket legs. The platform was installed onto the legs of the jacket by ballasting the pontoon. Dockwise was responsible for this phase. Mammoet has then used jacks to lift the platform into its final position on the jacket. Final position ofthe platform was reached on Friday 18th July. The 83 Metre long, 56 metre wide and 26 metre high SylWin alpha platform is the largest of its type. Earlier this year, Seaway Heavy Lifting used its crane vessel Oleg Strashnov to install the 5, 800Mt jacket. The Oleg Strashnov is one of the world’s ‘strongest’ crane vessels but it is not strong enough to lift the SylWin alpha jacket. Therefore, the decision was taken to add additional buoyancy in the form of buoyancy

megawatt. Grid manager TenneT, Siemens’ customer, is responsible for the connection of the wind farms to, in this case, the German high voltage grid. The SylWin alpha platform transforms the alternating current generated by the wind turbines into direct current that is transported via a 160km long seabed cable and a 45km long underground cable to the onshore Büttel high-voltage station. As a contribution to sustainable energy provision, Northern Europe already has 40 offshore wind farms in operation, another 40 will be installed in the coming 10 years. TenneT, the grid manager, is installing the offshore electricity grid in the German and Dutch sectors of the North Sea to which the wind farms will be connected. Dutch offshore companies are playing an important role in installing the wind farms and the electricity grid.

“Power socket at sea” tanks and to ballast the pontoon on site. This complicated operation has been preceded by more than a year of preparatory work. The 83 Metre long, 56 metre wide and 26 metre high SylWin alpha platform is the largest of its type. Earlier this year, Seaway Heavy Lifting used its crane vessel Oleg Strashnov to install the 5, 800Mt jacket. The Oleg Strashnov is one of the world’s ‘strongest’ crane vessels but it is not strong enough to lift the SylWin alpha jacket. Therefore, the decision was taken to add additional buoyancy in the form of buoyancy tanks and to ballast the pontoon on site. This complicated operation has been preceded by more than a year of preparatory work.

SylWin alpha platform

The SylWin alpha converter platform will serve as a ‘power socket’ for the DanTysk, Sandbank and Butendiek wind farms, which together comprise 240 wind turbines and represent a generating capacity of 864

Jan Willem van der Graaf, CEO Seaway Heavy Lifting: “With the installation of the 20,000 Mt (including its jacket) Sylwin alpha platform, Seaway Heavy Lifting and its partners have completed a challenging offshore operation. Our vessel, Oleg Strashnov, and crew did very well on the complicated jacket installation. In addition, a float over this size is a first in the North Sea. Together this made for a signature offshore installation project. We see this as an excellent example of what Seaway Heavy Lifting has to offer the developing offshore wind sector in Northern Europe.” This article is courtesy of Seaway Heavy Lifting with contribution of OGI’s Emma Patten, design by Anja Istenic. Photo credit: Seaway Heavy Lifting & the Bau der Offshore-Konverterplattform Sylwin Alpha, Netherlands.

SPECIAL: WIRE & ROPES

When it Comes to Major Heavy Lifts, Do You Have the Right Rope or Wire For the Job? Hans Coenen knows a thing or two about what needs to be done when you have a massive lift operation in your midst. One of the most important factors is the size, make and type of rope or wire you are using. Our Emma Patten sits down with one of Europeâ&#x20AC;&#x2122;s most storied rope and wire manufacturers, the Hendrik Veder Group. We speak with their Director of Services and Heavy Lift to find out more.

Deep sea heavy lifting

Emma: The Hendrik Veder Group is an amalgamation of a few different wire and rope companies. Some of them have a quite a storied history such as G. Van der Lee Rope Factory & Hendrik Veder. Could you explain to our readers the roles these different companies play in your business model? And how the Hendrik Veder Group came to be?

Heavy lift specialist, Mr Hans Coenen wire ropes, and lifting and towing materials for offshore as well as onshore customers. G. van der Lee Rope Factory, established in the 16th century, is member of the Hendrik Veder Group since April 2013. At their production location in Oudewater, NL a complete range of ropes are manufactured, fabricated to final products and certified, serving predominantly customers in offshore and maritime industries, and government and defence. Van der Lee adds fibre rope specific knowledge and traditional skill to the Hendrik Veder Group. In December 2013, Hendrik Veder Group and Aberdeen based ATR Group have established a strategic partnership with both partners taking an equal stake in Myhre Rope Services AS, the new name for Cosalt Offshore Norway. Emma: The diameter of a steel wire rope is important to the end user, but so is the ropes construction. There are many different rope classifications depending on their usage. EPC contracting, construction and heavy lift operation springs to mind. Could you explain which types of HVG steel wire ropes are optimal for the Oil and Gas and Offshore Industries? Coenen: Most commonly used are 6 and 8 strand IWRC Warrington Seale steel wire ropes with a tensile strength of 1770 through 1960 N/mm2. Normally these tensile strengths are sufficient enough, with respect to the capacity of lift required by client. In cases where higher capacity required, Hendrik Veder Group is willing to work closely with clients in order to utilize other tensiles, MBL (Minimum Break Loads) of the component ropes and/or construction. IWRC, or Independent Wire Rope Core, have a higher tensile and bending breaking strength than a fibre core rope and a high resistance to crushing and deformation. Warrington-Seale type ropes are characterized by the comparatively big number of wires in strands and consequently high flexibility. Besides 6-strand, 8-strand models are also used often. All in all, these wire ropes provide excellent fatigue and abrasion resistance,

and successful application in a corrosive environment. If required, we can provide specific lubrication of a wire rope. This offers reduced friction, corrosion protection and lubrication in the core, but also inside wires and on the exterior surfaces. We always manufacture in accordance with established international guidelines and quality standards such as IMCA M 179, EN 13414-1, 13414-3 and ISO 7531.

“

Hendrik Veder Group as a whole has a wide sphere of activities. It comprises activities in the area of heavy offshore lifting, with a specialism in cable-laid slings and grommets.

“

Coenen: Hendrik Veder, RopeQuip, European Rope Services – together with Wire Rope Services and Industrial Ropes – have merged into the Hendrik Veder Group in September 2012. Hendrik Veder Group as a whole has a wide sphere of activities. It comprises activities in the area of heavy offshore lifting, with a specialism in cable-laid slings and grommets. Furthermore, the group is wholesaler of wire ropes in offshore, maritime, automotive, industrial, and agricultural markets. In addition, Hendrik Veder Group is active in the distribution, confectioning and testing of steel

Emma: From consulting with many of our readers in Europe we’re finding from time to time, a company may encounter a potential heavy lifting operation which seems nearly impossible or has seldom been performed. What would you recommend for situations where research and development is needed to provide the correct solution? What types of assurances can be given (if at all) about delivery, quality assurance and / or certification? Coenen: One very important reason to work with Hendrik Veder Group is our expertise and experience with difficult lifting operations, or those operations seldom performed. Very often solutions developed in the past for other clients can be extrapolated (converged, combined) to new solutions. For example, for Stevedore Companies we produced small sized steel wire rope mats to lift loads of aluminium ingots. Once we needed to assist with developing a solution for lifting

Cable laid slings - courtesy of HVG

an oil rig (project name Brent) by its floaters. The force spreading nature of mats, that would not indent these hollow structures, turned out to be the perfect solution. And Hendrik Veder Group has the expertise to develop these mats in a large size format. We comply with various internationally recognised certification and quality control institutions. These certifications and the approval of these institutions is our guarantee of excellence, sustainability, and safety. Emma: Could you provide our readers an example where a tough offshore heavy lift project was completed recently using HVG wire rope slings? Coenen: Last year, Hendrik Veder Group has produced two cable laid slings with a gigantic length of 280 meters each. To our knowledge, these are the world’s longest cable laid slings ever produced. Terminated with two hand spliced soft eyes and weighing 63 MT each, the cable laid slings were used by Saipem for subsea field installation in the Åsgard field in the Norwegian Sea. In the meantime, these two cable-laid slings returned to our premises in perfect shape. We also delivered very recently cablelaid slings that were used to remove Statoil’s 2/4-S jacket platform. These slings were the thickest of its kind – 424 mm - and were produced in the shortest possible time. Emma: HVG does not only produce steel wire ropes. One of your most storied additions to the group, Van der Lee, is a manufacturer of natural and synthetic fibre rope products.

What are the prime applications for these types of ropes for the offshore industry? Are you finding that synthetic fibres are the best option available for all applications in the sector? Coenen: For all applications? No, not for all, but for specific applications it is. Especially Dyneema® based ropes. Using these HMPE (High Modulus PolyEthylene) fibre over wire in heavy lift slings during wind farm installation offers a number of advantages: the differences in weight and ease of handling, protection from abrasion, and longer lengths are available. For working in deeper waters, ropes made with Dyneema® have many advantages. They are capable of replacing steel wire size-for-size, a Dyneema® based rope is just 15% of the weight, and actually weightless when submerged. This means the full winch capacity is available for lifting at all depths in ultra-deep operations. Lightweight, compact ropes made with Dyneema® have flexible tension members meaning they are easy to handle on board by divers or by Remotely Operated Vehicles. Many offshore applications – including turret pull-in ropes, stinger ropes, anchor retrieval lines and riser tensioning ropes – benefit from replacing steel wire with ropes made with Dyneema® Synthetic fibres increase the application options for fibre rope. However, the ‘old fashioned’ materials and techniques are still appropriate for certain purposes. Emma: Could you enlighten us with a specific case study or interesting story where HVG products were used

in a significantly important operation, for a client? Coenen: We have been working in close collaboration with a client looking for a technical solution in Heavy Lift. In this lift, two cable-laid slings had to be attached to each-other (eye-to-eye ) but not with a shackle. The problem in this case was that the “rigging” had to be disconnected by means of an ROV. The solution we came up with was to “reeve” a 4” wire rope sling between two tri-plates (sheaves were installed, onto these tri-plates). The capacity of the reeved 4” wire rope (as it was reeved in a 10 part configuration) exceeded the capacity of the cable laid slings, thus making it safe. As the 4” wire rope was a single component rope, it was quite easy for the ROV to cut this particular wire rope instead of cutting a big diameter cable laid sling and/or shackle. In addition to this particular solution, the project also cut down on the client’s costs as this client’s 4” cable was much cheaper than “giving up” a cable-laid sling. The project is still ongoing. Emma: Alright then Mr Coenen, thank you very much for your time. Coenen: You’re welcome. This interview was conducted by Oil and Gas Innovation’s Emma Patten - Investigative Journalist and Hendrik Veder Group’s Hans Coenen - Director of Services and Heavy Lift. For more information contact Hendrik Veder Group at: info@hendrikvedergroup.com or visit: www.hendrikvedergroup.com

SPECIAL: METERING

Oil and Gas Innovation Interviews Energy Project Solutions, Expert in the Design and Manufacturer of Meters Now Being Used on FPSOs Based in Norfolk, United Kingdom, Energy Project Solutions (EPS) is a flow measurement solutions provider to the offshore and oil and gas industries around the world. OGI sat down with members of the team to discuss the positive impacts for oil and gas companies using various types of flow measurement instruments, particularly in operations involving the use of FPSOs which are increasingly prevalent especially among deep water drilling operations in places such as Brazil, for example.

Meter2 being used on the FPSO OSX3

OGI: Could you start by explaining Energy Project Solutionsâ&#x20AC;&#x2122; credentials and experience in terms of the designs and manufacture of flow measuring instruments for the oil and gas industry? We understand you are one of the leaders in the field. Could you tell our readers

Meter2 di

the breadth of your experience, how long you have been active, how many metering systems you have designed and your worldwide reach? EPS: The original team members had previously worked together for a company owned by the American corporation FMC Ltd,

based in Thetford in Norfolk. This particular company specialised in the design and supply of a range of DP metering products, including orifice meters, venturis, restriction devices and similar products. A feature of the new team formed at EPS Ltd

was the fact that although we could provide evidence of metering experience, we also could turn to previous experience in a wide range of industries. We felt this was most important, as the last thing that we could afford to do was to create another company producing what we described as “me too” metering. We came into existence in May 2010, so in that sense we are still very much the new kids on the block. Do we claim to be an absolute authority on all things metering? No, most definitely not. But we do celebrate what sets us apart, and that is innovation in orifice metering, bringing an old technology into the 21st century. There are essentially three layers to our orifice meter offering, with a conventional single chamber, then double chamber, followed by our new product called meter2 di. We have this product rapidly being established in many areas of the world, with an increasing foothold on FPSOs. OGI: Safety, reliability and certification are always important to potential clients when investing in flow control products, especially meters. Could you help our readers understand why quality assurances are so important for flow measurement equipment and what sort of safety standards and quality controls are in place and/or have been awarded to EPS? EPS: Yes, a very good question! Well of course the design code sets the level of accuracy, so in that sense if the design is to the appropriate code then the accuracy can be guaranteed. We claim no enhancement over competitor products with regards to accuracy, but with regards to safety, that is quite another matter. EPS quite rightly claim that meter2 di is very simply the safest meter available anywhere in the world today. As our design criteria we took Health and safety Guidelines 253 category 2 for proven isolation. By complying with these guidelines, we are not only able to isolate twice instead of once, but we are also able to prove the integrity of the isolation by introducing the use of two independent pressure gauges. This removes all uncertainty with regards to the safe use of the meter during inspection or maintenance. EPS offer all products to a variety of certifications including PED, NORSOK and ILAC. OGI: From our own investigations we have found that the useful functionality of metering systems for flow control, both gas and liquid, in the oil and gas industry is to increase a client’s margins. Could you explain how EPS meter design and manufacture helps firms do this? How does the actual process work from the beginning of the product lifecycle until the actual application of the

technology and the positive changes it has on a client’s flow control? EPS: There are several aspects to the benefits that a client can expect by implementing the use of meter2 di and the EPS plate0 (A plate that can only be inserted the correct way). As any operator knows, the incorrect insertion of an orifice plate can give an inaccuracy of up to 15%, costing operators huge sums of money. The most obvious ones are the speed with which examinations of the orifice plate can take place. Gone are the onerous requirements of the safety officer giving clearance for work to commence following isolation of the line there is no isolation of the line for this type of work, as the meter can demonstrate safe isolation solely on the meter. All associate pre-planning becomes completely unnecessary. Along with this, there is no deferment of gas, all of which are financial issues. The meter2di allows for the elimination of back up streams giving huge savings on materials and deck weight. Recent studies have shown that on one particular project the elimination of back up streams had the potential to save over $1 million. We also recommend use of predictive monitoring equipment such as Prognosis. Such equipment allied to meter2 di results in OP inspection being based on need rather than a pre-determined maintenance regime. Team this up with the EPS long life orifice plate which has 3 times the life of a duplex orifice plate and your client has some pretty impressive financial savings. OGI: In some offshore regions such as Brazil, drilling in consistently going deeper and deeper offshore. This has given rise to FPSO platforms which has changed many of the requirements needed for offshore oil extraction operations. Could you elaborate on one of your products, the meter2di series, which seems optimal for this type of scenario? EPS: We are indeed quite proud of our reputation for supplying equipment for FPSOs. Do we take credit for seeing this potential? Absolutely not, in reality it was experienced metering professionals who spelled out to us exactly what the benefits could be in terms of the reduction of OE by the elimination of back up lines. This gave a corresponding reduction in space requirement, and the weight also went down in direct proportion. That’s a lot of “wins” from one situation. Of course this is always against a back-cloth of greatly enhanced safety.

EPS quite rightly “ claim that meter2di

is very simply the safest meter available anywhere in the world today.

”

EPS: Again, the same benefits apply. There is an ever-increasing focus on safety, but deck weight will always be an issue as well, as will start up costs and space. With the use of Meter2di, back up streams can be completely eliminated. This has huge financial savings to both the operators and the EPC’s. With un-manned rigs there is little appetite for sending service technicians to check orifice plates when there is now the technology to conduct work on an only-when-required basis. OGI: Finally, EPS has recently received orders from the likes of Emerson, Petrobras, and a BP consortium. In particular for the Santos basin projects, the Meter2 series will be used. Could you provide us with an example or a case study where the Meter2di has been useful in an offshore operation? EPS: Our most significant breakthrough came when we supplied meter2 di for SBM on their FPSO supply to Petrobras called Ilhabela. This gave the most dramatic example of how to get all the benefits in just one location. Our most prestigious order is undoubtedly the one which is ultimately for BP for Shah Deniz. This does not make capital out of the elimination of back up lines, but we are very proud to have been selected to supply product for such a high profile customer. This interview was conducted by Oil and Gas Innovation’s Emma Patten - Investigative Journalist and Energy Project Solutions’ Kim Ruthven - Sales and Marketing Director. For more information or to find out how Energy Project Solutions can help your operations or to find out more about the Meter2di please contact EPS at: +44(0) 1842 768312 or via email at: sales@epsltd-uk.com

There is now a clear picture merging that conventional orifice meters represent the past, and that proven isolation represents the future. OGI: Why is a dual chamber orifice with ‘double isolation’ meter so well suited for offshore applications?

INDUSTRY NEWS: EUROPE

Norsea Group Makes Long-term UK Commitment NorSea Group (UK) Limited is making a major, long-term commitment to the UK with the announcement that it will take over operatorship of Smith Quay and Embankment at Peterhead on a 10-year agreement as of September 1. NorSea Group also has a 15-year lease at South Quay in Montrose and a long term agreement with Scrabster Harbour Trust. John Wallace, CEO at Peterhead Port Authority is delighted to welcome NorSea Group to the Port given their profile within the industry, personnel and resources. “We built up a strong portfolio of clients at the Smith Quay base, but it became apparent that we needed a professionally focused and integrated company such as NorSea Group to continue the success and provide the level of service expected at Peterhead, to grow this business further. NorSea Group are synonymous with safety and service, I warmly welcome them and look forward to this partnership blossoming.” The announcement of the new agreement with Peterhead Port Authority, represents the next phase of NorSea Group’s plans for ongoing increased activity on the UKCS, and follow NorSea Group’s acquisition of the Danish base and logistics company, Danbor, earlier this year. Danbor was also established in UK at the time of the purchase, but the UK office has now been merged with NorSea Group (UK) Ltd. Merger of the two companies was completed this month and they will now trade as NorSea Group (UK) Limited. The merger secures NorSea Group’s longterm plans to service oil and gas operators, service companies and drilling contractors through its offices and warehouses in both Aberdeen and Montrose. “When we signed an agreement with Scrabster Harbour Board and opened our office in Aberdeen last year, we did so with the intention of building a significant presence in the UK,” says UK MD, Kim Christensen. “The past 12 months has seen considerable company growth within the UK and we now have a major presence in four key Scottish ports – Aberdeen, Montrose, Peterhead, Scrabster with additional service provision at Lerwick and Invergordon.” Together with their other bases ; nine in Norway, one in Denmark and one in Holland, NorSea Group can now offer a unique coverage of the North Sea Basin. NorSea Groups Director of International and Project Operations, Knut Magne Johannessen continues: “We have made a long-term commitment to the energy sector in the UK and we will continue our plans for future growth. Traditionally known as a service provider for the oil and gas industry, our purchase of Danbor has given us the additional resources and facilities we needed to support our intention to provide a full range of services to the renewables and decommissioning markets, both on and offshore.”

Expro Plans New Base and Builds on $10m Well Test Investment International oilfield services company, Expro, plans to open a major new base in Tananger, Norway in summer 2015. The 19,000 sqm facility will consolidate the company’s three current Stavanger area locations and house Expro’s Well Testing and Drill Stem Testing product lines currently operating in the Norwegian Continental Shelf. The base will consist of an office building equipped for 100 staff, yard (5000 sqm) and workshop (10,600 sqm). The new workshop will have the facility to rig-up four well test packages, and service a further six, simultaneously. The company currently has over 250 staff based in Norway and operating offshore. The new facility will complement its other Norwegian offices in Bergen and Haugesund. Keith Palmer, Europe CIS Region Director, comments: “Expro is fully committed to maintaining its position as the market-leading well test company in Norway. “We continue to see our business in Norway expand and as such have outgrown our existing facilities. In addition to the commitment to a new facility, Expro has invested over $10m in capital expenditure for new equipment in Norway to service well test projects over the past two years. “The design of our new base will allow us to efficiently manage and maintain our equipment whilst providing clients with specialised staff and industry-leading service delivery. Furthermore, the workshop and pressure testing facilities at the new base have been fully designed to ensure the highest health, safety and environmental standards.” Expro will be exhibiting at Offshore Northern Seas (ONS) in Stavanger, Norway on Stand 251, Hall B from 25-28 August 2014. In combination with its Well Flow Management Academy ‘Well Test Live’ demonstrations, Expro will feature a range of product lines including Well Testing and Commissioning, Subsea, Meters, PowerChokes®, Wireless Well Solutions, DST/TCP and SafeWells well integrity software.

Europe’s Energy Security Begins in the North Sea Supply security in Europe has traditionally always begun on the continent’s own doorstep. Martin Bachmann, Member of the Board of Executive Directors of Wintershall responsible for Exploration and Production, firmly believes that this will remain so in the future too. Speaking at the international exhibition Offshore Northern Seas (ONS) in Stavanger, he said, “The North Sea – and particularly Norway – will be extremely important for Europe’s supply of oil and gas in the future too. Norway has good resources, is politically stable and has very good infrastructure.” Wintershall plans to continue expanding its activities on the Norwegian Continental Shelf considerably. Norway is Germany’s most important energy supplier after Russia. Last year, for example, almost 30 percent, in other words nearly one in three cubic meters of natural gas imports came from the Scandinavian country. The German population also recognizes this, as a recent survey conducted by the public opinion research institute Forsa and commissioned by Wintershall shows: 78 percent of Germans would favor Norway as a reliable partner to make up for declining natural gas production in the European Union. 62 percent named Canada, followed by the USA (45 percent) and Russia and the Middle East (with 38 percent each). Wintershall continues investments in the Norwegian Continental Shelf Norway is a growth region with special importance for Germany’s largest internationally active oil and gas producer. According to the business and investment magazine “Kapital”, out of the 500 largest companies in the whole of Norway, last year Wintershall Norge was the company that grew the fastest. Wintershall developed into one of the largest producers of oil and gas on the Continental Shelf during this time. An important milestone in this development was the partnership it entered with Statoil in 2012. With the asset swap of oil and gas fields, Wintershall not only took over the operatorship of a producing platform – Brage – in Norway for the first time in 2013, it also increased its daily production in Norway thirteenfold to 40,000 barrels of oil equivalent. “We will continue resolutely on our growth course in Norway and already have our sights set on the next target of 50,000 barrels per day by 2015,” Bernd Schrimpf, Managing Director of Wintershall Norge, says. The company plans to achieve this production target with the fields Knarr and Edvard Grieg, amongst others, which are currently being developed, and in which Wintershall holds working interests. “We are paying particular attention to the Wintershall-operated fields. We already launched an investment program for the exploration and development of our discoveries in Norway by 2015 worth up to € 2 billion,” says Schrimpf. “And we are sticking to it.” The Wintershall-operated Maria discovery, with its estimated production volume of around 130 million barrels of crude oil, in addition to just over two billion standard cubic meters of natural gas, is set to begin production in 2018. Natural gas – energy with a future At the ONS Bachmann highlights the importance of the long-term supply security of natural resources while discussing the “Energiewende”, or energy transition, in Germany, an undertaking that is being closely monitored by the international energy sector. Bachmann underlines the potential of natural gas in particular: “When it comes to making national economies more environmentally friendly and at the same time more competitive, then there is no alternative to natural gas. There is no other technology that can implement climate protection so effectively,” says Bachmann. The USA, for example, saved 740 million tons of CO2 between 2007 and 2012 by using more natural gas. Furthermore, America is enjoying a robust re-industrialization. “We find a different situation in Germany, where the energy transition was adopted. Here coal is increasingly being used as a fuel and natural gas is having to take a back seat – with grave consequences,” Bachmann explains. Although the Germans are paying over € 23 billion for renewable energies subsidies in 2014 alone, CO2 emissions there are on the rise again. This trend could be reversed cost-effectively by using more natural gas, as a new study by the Institute of Energy Economics at the University of Cologne shows. Germany could save around 40 percent of its CO2 emissions in the power segment alone compared to 1990 levels if it replaced coal with natural gas. “The energy transition in Germany shows that focusing energy policy solely on renewable energies is akin to leading the country up a blind alley. Idealism alone is not enough. Pragmatism is just as important. That would enable us to turn our attention back to natural gas as a driving force and cornerstone of positive change in the energy system,” Bachmann concludes.

INDUSTRY NEWS: NORTH AMERICA

Linde Engineering Expands to Better Serve the Petrochemical Industry in North America Technology company The Linde Group has added a petrochemical plant business unit to its Engineering Division offices in Houston, TX. The new regional business unit broadens Linde Engineering’s capabilities in North America and will serve petrochemical customers on a wide range of projects, from consulting and technical support, revamp and expansion studies to EPC (engineering, procurement, and construction) execution of mid-size projects. In addition, the new unit plays a role in the project execution of mega-projects, such as the large-scale ethylene plant for ExxonMobil at the renowned Baytown complex. The go-ahead for the Linde-Bechtel consortium to build this plant was announced in May. Also, the recently announced Enterprise Framework Agreement with Shell Global Solutions International B.V. will be supported from the Houston office. “With the increase in raw materials from U.S. shale gas supplies, investment in new and existing production assets is fully underway,” said Bruce Hensinger, President and CEO Linde Engineering North America. “This capacity expansion puts our feet on the ground in the centre of the North American petrochemical industry. Our wide range of processes and upgrade solutions for the industry coupled with a long experience in project management qualifies Linde Engineering as one of the top international EPC companies.”   Linde Engineering offers solutions for the petrochemical industry with a focus on olefins, as well as for the production of polyethylene (PE) and polypropylene (PP). Linde’s highly-skilled engineering and design staff have proven to take creative approaches to optimizing plant design, resulting in a large number of satisfied customers in the petrochemical industry. Collection of performance and operating data has provided Linde with substantial experience to design increasingly efficient plants. This is the basis of Linde’s leading position in petrochemical processing technologies worldwide. About The Linde Group   In the 2013 financial year, The Linde Group generated revenue of EUR 16.655 bn (USD 23.1 bn), making it the largest gases and engineering company in the world with approximately 63,500 employees working in more than 100 countries worldwide. The strategy of The Linde Group is geared towards long-term profitable growth and focuses on the expansion of its international business with forwardlooking products and services. Linde acts responsibly towards its shareholders, business partners, employees, society and the environment – in every one of its business areas, regions and locations across the globe. The company is committed to technologies and products that unite the goals of customer value and sustainable development.

Airgas Opens New Location in Dickinson, North Dakota to Service Bakken Shale Oil Region Airgas, Inc. (NYSE: ARG), one of the nation’s leading suppliers of industrial, medical, and specialty gases, and related products, announced that it has recently opened a new location in Dickinson, North Dakota, significantly enhancing its local product and service capabilities for customers in the Bakken shale oil region. “Our comprehensive product and service offering is tailored to meet the unique needs of customers in the energy industry, particularly in oilfield logistics and operations, well completions and production, and pipeline construction and maintenance, as well as customers involved in the fabrication of metal components and structures that are a critical part of the energy sector value chain,” said Airgas President and Chief Executive Officer, Michael L. Molinini. “Our new location in Dickinson, North Dakota, brings us much closer to our customers in this important region of the country.”   In addition to core industrial gases, welding-related equipment and safety supplies for in-store purchase or local delivery, customers in the region can now more easily access Airgas’ unrivaled national capabilities at a local level – from Red-D-Arc’s rental welders and power generation equipment to Airgas Specialty Gases’ complex hydrocarbon blends for BTU measurement and process stream analysis to the expertise of Airgas’ product and process specialists. Airgas On-Site Safety Services, which specializes in safety monitoring, certification, and equipment rental services at customer sites in the oilfield and construction industries, also serves customers through Airgas’ new Dickinson location.   The Bakken shale oil formation is located in western North Dakota and eastern Montana and extends into Canada. The formation has become one of the most significant sources of oil globally which, according to the United States Energy Information Administration, produces more than one million barrels of oil each day.

Wärtsilä Signs Long-Term Maintenance Agreement to Support Harvey Gulf ’s LNG Offshore Supply Vessels Wärtsilä, the marine industry’s leading solutions and services provider, has signed a long-term Technical Management Agreement with Harvey Gulf International Marine LLC (Harvey Gulf). This five-year agreement was signed in August 2014 and it covers Condition Based Maintenance and Dynamic Maintenance Planning for eight new offshore supply and multi-purpose support vessels - six liquefied natural gas (LNG) fuelled platform supply vessels and two offshore construction vessels powered by diesel fuel. The signed agreement ensures ideal running conditions and optimized maintenance for Harvey Gulf ’s new vessels. It ensures that their engines - 18 Wärtsilä 34 dual-fuel engines and eight Wärtsilä 32 engines - always run at the optimal level, with optimized fuel economy and maintenance costs. Technical management is based on continuous condition monitoring data and periodical inspections. The agreement also includes Online Remote Operational Support, which enables Wärtsilä’s technical experts to support vessels in real time, without the need for engineers to travel to the vessels. “Harvey Gulf ’s decision to become the leader in Clean Gulf of Mexico offshore operations has been enthusiastically accepted by oil company executives. And we are extending our partnership with Wärtsilä, through this Technical Management Agreement, to assure our new fleet of vessels are maintained to the highest standards of safety, reliability and availability,” says Shane J. Guidry, CEO of Harvey Gulf. “We are very pleased to expand our partnership with Harvey Gulf. This agreement reaffirms their commitment to the offshore oil and gas business in the Gulf of Mexico by adding safe and environmentally sustainable LNG fuelled vessels to their modern fleet. With this extended partnership, we will enable the safe and reliable operation of their offshore supply and multi-purpose support vessels throughout their lifecycle,” says Walter Reggente, Service Director of Wärtsilä North America. Reducing maintenance costs and increasing vessel’s uptime through Condition Based Maintenance Condition Based Maintenance system brings flexibility to operations as maintenance intervals are optimized. The system enables feeding engine parameters into Wärtsilä’s database, after which they are evaluated by specialists at the Condition Based Monitoring center. This enables early detection of performance issues, reduced downtime as well as optimized engine performance and fuel consumption. Knowing the actual condition of the engine allows the implementation of the Dynamic Maintenance Planning concept. This brings a significant opportunity to reduce operating costs by optimizing the timing of major overhauls and reducing the consumption of spare parts.

Foster Wheeler Awarded Contract for Heat Recovery Steam Generator in Mexico Foster Wheeler AG (Nasdaq:FWLT) announced today that a subsidiary of its Global Power Group has been awarded a contract by Iberdrola, for the design and supply of a heat recovery steam generator (HRSG). The unit will be installed at a cogeneration plant that Iberdrola is building at the Kimberly Clark de Mexico Ramos Arizpe Facility in Coahuila, Mexico.   Foster Wheeler has received a full notice to proceed on this contract. The terms of the agreement were not disclosed, and the contract value will be included in the company’s third-quarter 2014 bookings.   Foster Wheeler will design and supply the HRSG and provide advisory services for erection and start-up of the unit, which will incorporate a dual pressure level design with the capability to produce steam with or without combustion turbine operation. The HRSG will be coupled to a GE LM6000PH combustion gas turbine. Commercial operation of the HRSG is scheduled to begin during the first quarter of 2016. “Foster Wheeler’s HRSG will help improve reliability, ease of maintenance, and thermal efficiency,” said Byron Roth, Chief Executive Officer of Foster Wheeler’s Environmental and Industrial Group. “Iberdrola’s decision to select Foster Wheeler for this important project confirms its confidence in our product.”     Foster Wheeler AG is a global engineering and construction company and power equipment supplier delivering technically advanced, reliable facilities and equipment. The company employs approximately 13,000 talented professionals with specialized expertise dedicated to serving its clients through one of its two primary business groups. The company’s Global Engineering and Construction Group designs and constructs leading-edge processing facilities for the upstream oil and gas, LNG and gasto-liquids, refining, chemicals and petrochemicals, power, minerals and metals, environmental, pharmaceuticals, biotechnology and healthcare industries. The company’s Global Power Group is a world leader in combustion and steam generation technology that designs, manufactures and erects steam generating and auxiliary equipment for power stations and industrial facilities and also provides a wide range of aftermarket services. The company is based in Zug, Switzerland, and its operational headquarters office is in Reading, United Kingdom.

INDUSTRY NEWS: BRAZIL

Wood Group Kenny Wins Two Contracts with Petrobras Wood Group Kenny (WGK) has won two contracts with a total value of over $2 million with Brazilian operator Petrobras.   In the first, Wood Group Kenny has begun a conceptual engineering study of two alternatives of pipeline heating systems for the Petrobras pre-salt Lapa field, waterheated pipe-in-pipe (WH-PiP) and electrically trace-heated pipe-in-pipe (ETH-PiP). The project aims to provide Petrobras and its partners, BG and Repsol Sinopec, with the basis to evaluate the technical feasibility of the south west area tieback on the field and determining the most cost-effective technology. The application of active heating pipeline technology would be a first in a pre-salt environment. Wood Group Kenny’s scope on this contract includes the studies of flow assurance analysis, mechanical and installation design, thermo-mechanical analysis, material selection, and technological gap evaluation. Cost assessment and an installation capabilities survey will also be conducted within the scope of the study. Wood Group Kenny is supporting Petrobras and its partners from their offices in Rio de Janeiro, Houston and London, to address the multidisciplinary scope on the pre-salt Lapa Field. The second contract will focus on engineering support to provide conceptual, basic and detailed design deliverables to their subsea engineering group. In addition, Wood Group Kenny will be responsible for a set of engineering studies to be carried out within the contract period.   Leveraging on its global expertise in subsea and pipeline engineering, Wood Group Kenny will focus on optimizing riser, pipeline and equipment engineering design, with the objective of increasing the competitiveness of the rigid solution for Petrobras’ subsea development. Hugues Corrignan, director of Wood Group Kenny do Brasil said, “Wood Group Kenny has already worked with Petrobras on several projects and the award of these two contracts recognises the strength of the relationship with a principal client in the area. “We are particularly pleased to be selected to support Petrobras in these challenging projects and have the opportunity to positively contribute to the introduction of innovative technologies in the Brazilian environment.”     The Lapa Field is located in 7,021 feet (2,140 metres) of water, roughly 170 miles (273 kilometres) off the south coast of Rio de Janeiro within Block BM-S-9. In December 2013, Petrobras submitted a Declaration of Commerciality (DoC) to Brazil’s ANP for the pre-salt Carioca field in block BM-S-9 (renamed Lapa). The DoC proposes that Lapa holds recoverable volumes of 459 MMboe.

Petrobras Signs Agreement with Japan to Fund Construction and Conversion of Platforms Petrobras has signed an agreement with Japanese export credit agency Nippon Export and Investment Insurance (NEXI) and Mizuho Bank to issue a loan guarantee for the sum of US$500 million assigned for projects to build and convert 12 floating production, storage and offloading (FPSO) platform hulls. On Friday, August 1, at the Planalto Palace in Brasília, the previously signed documents were formally exchanged in the presence of Brazilian President Dilma Rousseff, Japanese Prime Minister Shinzo Abe, Petrobras CEO Maria das Graças Silva Foster, NEXI CEO Kazuhiko Bando, and Mizuho Bank Executive Manager Hiroshi Suchiro. The platforms are being built to develop pre-salt projects in the Santos Basin. Eight of them (P-66, P-67, P-68, P-69, P-70, P-71, P-72, P-73) are assigned to blocks BM-S-9 and BM-S-11, while the remaining four (P-74, P-75, P-76 and P-77) will be used in the onerous concession areas (Cessão Onerosa). Pre-salt now represents slightly more than 20% of Petrobras’ oil production in Brazil. According to the company’s Business and Management Plan, pre-salt will account for around 50% of its production in 2020. By this date, Petrobras plans to have doubled its output to 4.2 million barrels of oil per day.

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INDUSTRY NEWS: ASIA PACIFIC

Platts Report Announces Singapore Moving Towards FOB Straits Basis for Oil The expansion of Singapore as a leading Asia-Pacific energy hub, combined with the country’s moratorium on the development of further onshore storage, has led to the hub expanding beyond national borders to encompass infrastructure in Malaysia, according to the Platts Special Report “FOB Singapore Beyond Singapore –Towards FOB Straits” released at the Platts Crude Oil & Refined Products Forum in Singapore. Singapore’s storage capacity is a key reason for the country’s status as Asia’s leading oil trading hub. As Singapore’s storage terminal market has matured, further capacity growth has been curtailed by limited waterfront land availability. Market participants have embraced terminals in Malaysia and Indonesia to accommodate higher trading volumes, as supply and trading of oil has steadily climbed across Asia as a whole. “With Singapore’s land scarcity, it only makes sense for market participants to look beyond Singapore’s shores for more cost effective developments of new storage capacity,” said Jonty Rushforth, Platts editorial director of Asia and Middle East oil markets. “And we have seen a shift in market dynamics.”     These developments mean the oil industry is evolving from a specified loading of Free-on-Board (FOB) basis Singapore ports, towards a broader FOB “Straits” basis. Platts, a leading global provider of benchmark price references and pioneer in Asia oil price benchmarks, is engaging with interested parties across the market to expand the definition of its own assessments accordingly.”   Methodologies evolve through time and must continuously adapt to the changing conditions that are a hallmark of physical commodity markets,” said Calvin Lee, Platts senior manager of Asia markets reporting. “By being more flexible with the port locations that our price assessments embrace, we can better match the evolution taking place in oil movements, storage, refining and trading.”

Petrofac Awarded a Refinery Contract in Malaysia Petrofac, the international service provider to the oil and gas industry, has been awarded an Engineering, Procurement, Construction and Commissioning (EPCC) contract by PRPC Refinery and Cracker Sdn. Bhd. a subsidiary under the Petroliam Nasional Berhad (PETRONAS) group, Malaysia’s national oil and gas company; for a Refinery package in PETRONAS’ Refinery and Petrochemicals Integrated Development (RAPID) project in Pengerang, Johor, Malaysia. Worth more than US$500 million, the competitively tendered lump-sum EPCC scope of work includes three sulphur recovery units, two amine regeneration units, two sour water stripping units, a liquid sulphur storage units and a sulphur solidification package unit. Located in Pengerang, within the state of Johor, Malaysia; PETRONAS’ RAPID project is by far the largest liquid-based green-field downstream undertaking in Malaysia. It will have a 300,000 barrels per stream day refinery and will supply naphtha and liquid petroleum gas feedstock for the RAPID petrochemical complex, apart from producing a host of refined petroleum products, including gasoline and diesel that meet the Euro 4 and Euro 5 fuel specifications. RAPID is part of the bigger PETRONAS Pengerang Integrated Complex (PIC) development which comprises of RAPID and its associated facilities including the Pengerang Co-generation Plant (PCP), Re-gasification Terminal 2 (RGT2), Air Separation Unit (ASU), Raw Water Supply Project (PAMER), Crude and Product Tanks (SPV2) as well as central and shared Utilities and Facilities (UF). PIC is poised for its refinery start-up by early 2019. Subramanian Sarma, Managing Director of Petrofac’s Onshore Engineering & Construction business, commented: “This award represents another significant step in building our capability in the Asia-Pacific region. Malaysia is a core country for us, PETRONAS a key customer and we have a substantial physical presence in the country to support our ongoing projects and future aspirations.”

INDUSTRY NEWS: MENA

Dana Gas Secures US$ 100 Million Project Financing for UAE Offshore Gas Field (Zora Project) Dana Gas, the Middle East’s leading regional private sector natural gas Company, is pleased to announce that it has secured, through its wholly owned subsidiary Dana Gas Explorations FZE, a US$ 100 million Term Facility for the Zora Field Development Project. This facility will contribute the debt component of the financing needed to complete the project and bring the Zora gas field on-stream. The credit facility, with Emirates Bank NBD Capital Limited as Initial Mandated Lead Arranger, Bookrunner and Coordinator, will be provided by the following syndicated banks in their role as “Mandated Lead Arranger and Joint Bookrunners”, Emirates NBD Bank, Commercial Bank International, Commercial Bank of Dubai and Barwa Bank. Emirates NBD Bank will also act as the Global Facility Agent, Term Facility Agent, Security Agent and Account Bank while Barwa Bank will act as the Murabaha Investment Agent for the Shariah tranche of this loan. The repayment for the Term Facility is over a period of 15 quarterly investments and will commence in 2H 2015 on completion of the project and gas production goes on stream, subject to a cash sweep mechanism. The Term Facility is currently scheduled to mature on 30 November 2018. As of 30th June 2014, Dana Gas has spent approximately US$ 49 million as part of the equity financing for the project. Dr. Patrick Allman-Ward, Chief Executive Officer of Dana Gas said: “This financing agreement demonstrates the confidence leading banks and financers have towards the Zora project. The project work is proceeding as per plan and we remain committed towards bringing the project on-stream in the first half of 2015. Natural gas produced from the field will provide a much needed source of clean energy for the benefit of the Northern Emirates of the UAE.” The Zora Gas Field, which spans the territorial waters of Sharjah and Ajman, comprises a tilted fault block structure with a closure of some 25 km2. Once on-stream, Zora will provide an additional source of gas for local power generation in the northern Emirates with an expected production capacity of 40 mmscfd (6,650 boepd).

Technip Awarded a Significant Contract for New Refinery Units in the Kingdom of Bahrain Technip was awarded by The Bahrain Petroleum Company (BAPCO) a significant* contract on a reimbursable basis to develop the Front-End Engineering Design (FEED) of the refinery located in the Kingdom of Bahrain. The FEED contract covers four main work packages that include units aimed at processing the “bottom of the barrel” components to high value products, and all associated offsites and utilities to provide seamless integration with existing refinery facilities earmarked for retention post this major modernization. The project aims at enhancing the refinery configuration, by increasing the throughput from 267,000 to 360,000 barrel per day as well as improving the product slate and profitability. Technip’s operating center in Rome, Italy, in cooperation with Technip’s operating center in Abu Dhabi, United Arab Emirates, will execute the contract, scheduled to be completed at the end of 2015. Marco Villa, Technip Region B** President said: “We are proud to be associated to BAPCO for this major development of the refinery. The award confirms Technip’s leading position as partner of choice to provide high-end services for strategic investments. This reflects at the same time the importance to follow the client and have keen understanding of its needs, since the very early stage of an initiative”. With more than 50 years of experience in the oil-refining sector, Technip leverages its strong expertise in the design, construction or revamp of refineries in more than 75 countries. The Group provides leading-edge solutions worldwide. * For Technip, a “significant” onshore contract is ranging from €50 to €100 million. ** Technip Region B is composed of Italy, Greece, Eastern Europe/Russia, South America and Canada Onshore-Offshore.

INDUSTRY NEWS: AFRICA

Oceaneering Announces BP Angola Contract Extension Oceaneering International, Inc. announced that BP plc. has exercised both one-year options to extend the Field Support Vessel Services contract with Oceaneering for work offshore Angola on Blocks 18 and 31. Under this contract term extension, Oceaneering will continue to provide project management, engineering, and vessel services through January 2017. Two chartered vessels, the Ocean Intervention III and the Bourbon Oceanteam 101, will continue to be supplied during the contract term extension. Each vessel is outfitted with two Oceaneering work class remotely operated vehicles (ROVs) capable of working in 3,000 meters of water. The contract scope of work includes light subsea construction and inspection, maintenance, and repair services on existing and future subsea infrastructure. The contract has a provision for Oceaneering to continue to provide during the extension period, at BP’s option, a third vessel on a mutually agreed, as-needed basis. The third vessel currently being provided is the Bourbon Evolution 803, which is contracted through January 2015. M. Kevin McEvoy, President and Chief Executive Officer, stated, “We are very pleased to have secured this contract extension from BP, one of our largest customers. In support of this contract, we are also providing ROV tooling, asset integrity, and installation and workover control system services. This extension strengthens our long-term commitment to Angola, which is a growing market for our services and products.” Oceaneering is a global oilfield provider of engineered services and products, primarily to the offshore oil and gas industry, with a focus on deepwater applications. Through the use of its applied technology expertise, Oceaneering also serves the defense, entertainment, and aerospace industries. In accordance with the Safe Harbor provisions of the Private Securities Litigation Reform Act of 1995, Oceaneering International, Inc. cautions that statements in this press release which are forward-looking involve risks and uncertainties that may impact Oceaneering’s actual results. The forward-looking statements in this press release concern Oceaneering’s: expected continuation of delivery of project management, engineering, and vessel services; intention to continue supplying two vessels equipped with Oceaneering ROVs; anticipated continuation to provide ROV tooling, asset integrity, and installation and workover control system services; belief that the contract extension further reinforces its long-term commitment to Angola; and belief that Angola is a growing market for Oceaneering’s services and products. Although Oceaneering’s management believes that the expectations reflected in these forward-looking statements are reasonable, Oceaneering can give no assurance that the expectations will prove to have been correct. The forward-looking statements are made based on various underlying assumptions and are subject to numerous uncertainties and risks, including without limitation, changes in project design or schedule, contract cancellation, change orders and other modifications, and difficulties executing on the project. If one or more of these risks materialize, or if underlying assumptions prove incorrect, actual results may vary materially from those expected.

Acquisition of 40% Interest in the Ubima Field, Onshore Niger Delta Eland, the oil and gas exploration and development company with a focus on Nigeria and West Africa, is pleased to announce that Wester Ord Oil & Gas Limited, a wholly owned subsidiary of Eland, has agreed to acquire a 40 per cent participating interest in the Ubima Field from Allgrace Energy Limited. The most recent independent 2C resources estimate for Ubima is 34 MMbbl of oil (independent report prepared by AGR TRACS). There is also a significant upside 3C resource estimate of 66.9 MMbbl of oil with an extra 2C resource estimate of 97 Bcf of non-associated gas in two reservoirs. Ubima lies onshore in the northern part of Rivers State and has been carved out of Oil Mining Lease (OML) 17, which is held by Nigerian National Petroleum Corporation, The Shell Petroleum Development Company of Nigeria Limited, Total E&P Nigeria Limited and Nigerian Agip Oil Company Limited (the “Head-Farmors”). Ubima has 3D seismic coverage and four wells have been drilled in the field between the 1960s and 1981 with hydrocarbons being encountered in all four wells in multiple stacked reservoirs. The Ubima 1 well was suspended and identified for completion and production by the previous operator, but this programme was not executed and Wester Ord is planning to re-enter this well and perform an extended production test, oil produced will then be trucked to the nearest sales point prior to the Ubima export pipeline being in place. The Company believes that subsequently an initial four development wells can be drilled and put into production 9 to 12 months from commencement of the full work programme. The full work programme is estimated to require development capital expenditure of $125 million, however a proportion of this is anticipated to be met from early cashflows from the extended production test. Wester Ord entered into a farm-in agreement with the Farmor for a 40% interest and as consideration for the assignment, will pay a signature bonus of US$7 million to the Farmor and, contingent on production and receipt of Ministerial Consent to the transfer of the participating interest, a production bonus of US$3 million. Wester Ord also entered into a separate commercial agreement to fund the initial work programme. The terms of this agreement entitle Wester Ord to 88 per cent of production cash flow from Ubima until the costs have been recovered. The Company will guarantee the obligations of Wester Ord under the farm-in agreement and the signature bonus will be paid from existing cash resources. The Company is currently in discussions to increase the existing debt facilities to fund the Ubima development. The completion of the transfer of the 40 per cent. participating interest from the Farmor to Wester Ord is contingent on the approval of the HeadFarmors and the Nigerian Minister of Petroleum Resources. Pending receipt of Ministerial Consent to the transfer of the 40 per cent. participating interest, Wester Ord will exercise the rights and benefits of its 40 per cent interest in Ubima via the Financial and Technical Services Agreement which takes effect from completion. The Ubima Field was awarded to the Farmor by the Department of Petroleum Resources in 2011. The award also included a commitment to develop viable small scale gas utilisation projects within 30 months of commencement of production. This could include a small scale power generation project where the availability of electricity in rural areas is severely restricted. The Farmor since the award of the Ubima Field has to date not conducted any work on the Ubima Field and therefore there are currently no profits/losses attributable to Western Ords acquisition of 40% of the field. The field is close to existing infrastructure for the delivery of crude to market and Wester Ord are currently in discussions with The Shell Petroleum Development Company regarding the crude export tie in point. As a designated marginal field, Ubima will benefit from attractive fiscal terms available in Nigeria as part of the government indigenisation programme. Leslie Blair, CEO of Eland, commented: “The acquisition of Ubima is a very attractive and accretive deal for Eland on very positive terms. As the Technical and Financial Partner we will be able to lead the development and move quickly to bring these assets into early production generating strong cashflow for the benefit of all stakeholders.”

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INDUSTRY NEWS: RUSSIA AND CIS

Strategic Partnership Between Gazprom and Kyrgyzstan to Boost Socioeconomic Development of Republic Strategic Partnership Between Gazprom and Kyrgyzstan to Boost Socioeconomic Development of Republic. Bishkek hosted a meeting between Gazprom’s Management Committee Chairman Alexey Miller and Kyrgyz President Almazbek Atambayev. The parties addressed major cooperation initiatives in the oil and gas sector and noted that the comprehensive integration of the Kyrgyz energy sector into Gazprom Group would help with solving several issues of national importance. In particular, a large-scale investment program aimed at the reconstruction and upgrade of gas transmission and distribution networks of the Republic will enhance the reliability of gas supplies to industrial and residential consumers in northern and central areas of Kyrgyzstan and will also make it possible to supply natural gas to the country’s south. In addition, the participants considered prospects for exploration activities and touched upon the issue of expanding the collaboration in petroleum products sales on the Kyrgyz market. A focus was placed on the preparations for the heating season. It was noted that Gazprom would undoubtedly complete all the scheduled activities to secure unfailing gas supplies to Kyrgyz consumers during the forthcoming winter period. Summarizing the meeting, Alexey Miller and Almazbek Atambayev expressed their confidence that the strategic partnership between Gazprom and Kyrgyzstan would reinforce the energy security of the Republic and, in addition, boost the Kyrgyz socioeconomic development for years to come.

Gazprom to Fully Supply Belarusian Consumers with Natural Gas in Coming Winter A working meeting between Alexey Miller, Chairman of the Gazprom Management Committee and Igor Petrishenko, Ambassador Extraordinary and Plenipotentiary of the Republic of Belarus to the Russian Federation took place as part of the XIII International Investment Forum “Sochi-2014”. The parties discussed the current state and development prospects for the cooperation between Russia and Belarus in the gas sector. It was pointed out that Gazprom Transgaz Belarus, a subsidiary company of Gazprom, secured uninterrupted gas supply and transit and was a major tax payer in the Republic. This speaks for the strategic nature of the mutually beneficial cooperation between Russia and Belarus and helps in facing the future positively. Special focus was placed on the preparations for the 2014–2015 autumn-winter periods. Gas transmission facilities are being upgraded and overhauled in compliance with the set schedule. The work is underway on replenishing gas reserves in underground storages. Before the withdrawal season starts, the company is going to increase the operating reserve of marketable gas to 1.035 billion cubic meters in Belarusian UGS facilities, which is 12.5 per cent more than in 2013. The completion of these major works will help Gazprom to smoothly get through the heating season and fully supply Belarusian consumers with natural gas in the coming winter. The meeting participants also addressed Gazprom’s social projects in the Republic. For instance, Minsk hosted one out of two zonal rounds of Gazprom Neft Cup, Europe’s major International KHL Tournament among Children’s Hockey Teams this April. The remarkable and memorable event was a real present both for the participants and for the rooters. The company actively participates in projects aimed at early disease detection and urgent treatment of children. For instance, special-purpose equipment is being donated to medical centers within the program for early detection of hearing disorders. Moreover, thanks to Gazprom’s financial aid the reconstruction of the Brest Fortress memorial was completed and the new exhibition was opened to honor the 70th Anniversary of Liberation of the Republic of Belarus.

E&P SPECIAL: RIG INSPECTION

The Importance of Rig Inspections for Reducing Operational Costs and Increasing Safety Frequent and timely rig inspections can be a nuisance but end up saving time and money. To ensure maximum rig safety, early identification of potential risks and the taking of the appropriate measures to eliminate risk factors are needed. Oil and Gas Innovation interviews one of the world leaders in this field, Aberdeen Drilling Consultants. OGI: Could you start by explaining Aberdeen Drilling Consultantsâ&#x20AC;&#x2122; credentials and experience in terms of rig inspections? We understand you are one of the world leaders in the field. Could you tell our readers the breadth of your experience, how long you have been active, how many rigs you have inspected and your worldwide reach? ADC: ADC are an international, family owned company with a worldwide reputation, gained by providing the highest standard of Rig Inspection services to companies across the globe for over 29 years. Having conducted over 15,000 rig inspections in more than 85 countries, we believe our single-minded obsession with detail is the primary reason for our success, and the reason why we continue to be rated number one within the industry. Such close attention to details ensures that the engineers we employ, are not only of the highest calibre backed by years of experience, but also are able to work easily with rig personnel anywhere in the world. Our work frequently joins youthfulness and maturity, partnering seasoned oil field professionals with fresh-faced technology laden graduates. The benefits of this are numerous, valuable and sometimes legendary. Our work has led us to the development of our much-acclaimed TRAMS reporting system, unique to ADC, and a first for the industry. Not only does it deliver standardisation to the reporting process, it significantly reduces the reporting time frame, enabling, in some cases, an interim report to be available even before the engineers have left the rig. This has inspired the creation of our own online training facility, VIRTUAL ACADEMY which is approved by the Scottish Qualifications Authority (SQA) with courses accredited by both the IWCF and IADC. Written and developed by our engineers, many of whom are experienced oilfield veterans and all are subject matter experts, the teaching is uniquely designed to stimulate real competence through understanding based assimilation. And lastly,

no matter how we conduct business from first contact, interaction, communication and ongoing service, we know our clients appreciate the culture created at ADC. OGI: From our own investigation in the matter at hand, we have found that the primary recipients of rig inspection services are oil and gas producers, operators and contractors. One of the main reasons a company chooses to have inspections of their systems and facilities is to reduce downtime in their operations due to scenarios such as malfunction of systems and equipment. However, a thorough inspection may actually cause downtime itself. Can you explain if ADC Engineering can forecast the amount of downtime your potential client may experience during an inspection, and if there are possible measures which can be taken to reduce this cost to the client? ADC: Whether a rig is new from the yard Riser inspection

Integrated Controls or simply refurbished, our independent acceptance testing can not only ascertain whether it is ‘fit-for-purpose’ complying with identified standards and pre-set contractual agreements, but gauge the potential likelihood of future downtime resulting from equipment or systems failure. Recognising that the major concern within the rig community is downtime or non-productive time (NPT), its length, and how it’s managed is extremely important. Excessive downtime brings economic concerns, whilst restricted downtime impacts on HSE. What is abundantly obvious is that all activities undertaken during the downtime window need to be efficient and effective so as to achieve maximum results within the smallest time frame. It is because of this fundamental requirement that all ADC Rig Inspections utilise the unique TRAMS reporting system as the vehicle by which all inspections are conducted and completed. Working together with clients, results in producing a more efficient, streamlined inspection, resulting in reporting with consistent content, clearly identified close-out checklist and a dramatically tighter inspection and reporting time-line. TRAMS based inspections can be tailored to a specific client needs and can be applied to any stage of the life cycle of a rig. The TRAMS database can provide inspection history and trend analysis by allowing ADC to conduct detailed comparison of the previous work scope findings. OGI: In terms of equipment, regulatory requirements and safety, could you elaborate on the necessary requirements a rig must have to be ready to start drilling operations? Do these requirements vary greatly from region to region? ADC: Arguably the most significant area on any rig, BOP and well control constitutes the high-risk part of any oil and gas extraction process. To this end, ADC have developed a dedicated department whose sole remit is to specialise in inspecting and identifying potential risk, analyse consequence and

provide corrective actions so as to eliminate the potential negative impact on cost, time and safety. We believe it’s essential to involve and work with the rig contractor during the inspection process. In reviewing existing maintenance records and inspection reports as well as downtime history, our engineers can observe and report on shortcomings to help support and encourage best practice. OGI: If an operator was to use ADC’s services, what is the beneficial impact on the user’s costs and operational efficiency in the medium to long term future? ADC: Risk must constitute one of the most important areas within the oil and gas industry. Get it right and output and profitability are assured, get it wrong and both are jeopardised with potentially very serious consequences. At ADC we understand the significant impact risk management can have on business performance. Our rig inspection services provide a systematic evaluation of potential risks associated with the drilling rigs, their consequences and probability through the application of our inspection software for both qualitative and quantitative examination. As a third party we provide essential impartiality. ADC’s proactive approach, assessment of identified non-conformances and corrective actions aids in the mitigation of these risks for our clients. The application of consistency using TRAMS throughout each project and customisation of the Risk Assessment and Rig Inspection process allows ADC to tailor a solution to clients’ specific requirements. The early identification and intervention to resolve risk not only ensures projects stay on schedule and budget but also promotes greater ownership and partnership between client and contractor. OGI: I’d like to turn to control systems now. The modern rig nowadays is increasingly automated, and controlled by integrated control systems. This opens up new problems associated with equipment failures. Operators’ primary concern is avoiding downtime, how important is it that these systems are reliable?

ADC: It is essential that these systems are reliable. These systems are designed to improve safety and efficiency, which they do, but this comes at the cost of complexity with the attendant risk of downtime. One of the major problems with introduction of new technologies is that expertise in these new fields can be limited within an existing workforce used to working with legacy technologies. ADC recognises this and has invested heavily in training suitably talented and qualified engineers in the latest drilling technologies with the express intent of delivering a rig inspection service capable of accurately gauging the status of advanced control systems hardware, software and communications networks. The aim of this is to provide the ability to assess the functionality and capability, reliability, support and management of all aspects of modern electronic control systems. OGI: How does ADC’s Integrated Control Systems Inspection Services help rig operators ensure that their control systems are reliable throughout the whole life cycle? ADC: A typical example of this through life cycle involvement could be found on the recent introduction of a new rig jacking system. Following a control system software problem that had resulted in a jack up leg collapse, ADC ICSIS were involved in the early stages of the analysis of hardware and software modifications that had been embodied to resolve the cause of collapse. ADC witnessed

and assessed the content and conduct of the Failure Modes Effect Analysis (FMEA) of the system and participated in the jacking trials. Subsequent to this, ADC provided crew training and produced a training manual for operators and maintenance personnel. ADC was also involved in the assessment of the spares requirement for the system in order to maintain operational capability. ADC has provided advice during rig moving operations, support when problems were encountered with the system and conducted an incident investigation review. This expertise has reduced down time in real terms for operators, enabled them to operate in difficult circumstances and learn from teething problems encountered with this new system. In addition to this, ADC has advised on the software back-up procedures and management of change procedures for these systems to cater for the through life support of the system. OGI: Finally, could you provide our readers with one example or case study where ADC’s inspection services made a rig safer and more productive? ADC: The following example outlines a Pipe Handling System Test led by ADC following previous tests that the manufacturer had considered acceptable but that ADC had refused to accept. The reason that ADC’s test made the rig safer is because it highlighted incorrect settings in the Drilling equipment’s anti-collision system and made the rig more

efficient because it facilitated simultaneous drilling and stand building operations as described below. The ADC ICS specialist designed a revised pipe handling test procedure in order to address issues that had been evident during the previous Pipe Handling System tests conducted by the original equipment manufacturer (OEM) and that ADC considered to be unacceptable. The ADC test plan was designed to provide assurance that the drilling package could be operated, as per design, in auto and manual modes where appropriate under normal operating conditions. The content of the test was agreed between ADC and the Drilling Contractor Operations Department and sequence of events was agreed with OEM in order to improve the flow of events. The test sequences were completed as per the OEM documentation. However, it was considered that there was an Operational requirement to conduct offline stand building during drilling operations. Therefore, the auto driller system was used to move the top drive up and down during stand building operations (ADC had identified this gap in the commissioning procedures and had previously requested this scenario to be tested). During the test, this simultaneous operation caused a Zone Management System (ZMS) problem when the draw works were operated that prevented drill floor equipment from moving. ADC recognised that the ZMS functionality was designed to artificially raise the computer’s calculation of drill floor height and suggested that the computer drill flwwoor height value may be in error. OEM engineers reviewed these settings and found that the ZMS drill floor should have risen to 6m during Auto Driller operation. What is more, OEM investigations revealed that the software setting was set to 28m and that this error had prevented simultaneous Stand Building and Auto Drill operations. The OEM demonstrated the correct functionality when the issue had been resolved and stated that this had been found to be a base line software issue. Furthermore, this was discovered to be a fleet wide problem affecting another 4 rigs and the OEM thanked ADC for assistance in this matter. Thus the operational efficiency of a fleet of rigs was improved by allowing simultaneous drilling and stand building operations and a fault in a safety critical system was identified. This interview was conducted by Oil and Gas Innovation’s Emma Patten - investigative journalist and Aberdeen Drilling Consultants’ Jason McGill - Business Development Manager.

Inspection

For more information or to find out how ADC Rig Inspection can help your operations please contact Aberdeen Drilling Consultants at: +44 (0) 1224 209123 or via email at: info@adc-engineering.com

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28 & 29 OCTOBER 2014 Program Offshore Energy Conference Tuesday 28 October 2014

Wednesday 29 October 2014

09:30 - 18:00 09:45 - 10:00 10:00 - 12:00 10:00 - 11:30

09:30 - 18:00 10:00 - 11:30 10:00 - 11:30 10:00 - 12:00 12:00 - 13:30

10:15 - 12:00 12:00 - 13:30 14:00 - 16:00 14:00 - 16:00 14:00 - 15:30 14:30 - 16:30

Offshore Energy Exhibition Official Opening Master Class 1 Extending asset life: Offshore Maintenance Services Industry Panel Well plugging abandonment Master Class 2 Drilling & Dollars Panel North Sea E&P: New game and an old playing field Mexican petroleum industry reforms

Offshore Energy Exhibition evelopments in wave and tidal energy D Subsea processing Master Class 3 Regulations for â&#x20AC;&#x2DC;industrial personnelâ&#x20AC;&#x2122; on board offshore service vessels Master Class 4 Human Capital Panel Offshore Vessels: Market update

14:00 - 16:00 14:00 - 16:00 14:30 - 15:30 09:00 - 17:00

o-located event: Offshore WIND C Installation and Maintenance Conference

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Modern Engineering Methods Enhance Understanding of Well Operations and Reduce Technical Risks Meeting todayâ&#x20AC;&#x2122;s demand for energy requires the tapping of reservoirs that are more and more difficult to reach. Access to such deposits is made possible by advances in technology enabling wells to be drilled ever deeper, further and in more complex ways. This pushing of the boundaries results in wells operating in extreme conditions, meaning that traditional engineering methods are no longer adequate in the design of downhole equipment, tools and tool systems. Further adding to these technical risks and challenges, are increasingly strict environmental and cost pressures.

orking in extreme wells usually means having to deal with extreme downhole conditions that place great demands on tools and equipment. This makes reliability and robustness of tool systems and processes critical in controlling technical, environmental and cost risks. High temperature and pressures push tools and materials to their limits, necessitating a deep and integrated understanding of statics, dynamics, chemistry, materials science, fracture mechanics, etc. for their conceptualization and development. Additionally, the proliferation of tool systems required in meeting all the functional demands of extreme operations means that the interactions between them are increasingly complex. As a result, traditional engineering methods and simple design approaches are in many cases no longer sufficient. Instead modern, holistic engineering methods (such as those pioneered by the aerospace industry decades ago) are now required. In the past the oil and gas industry has not generally kept up with the advances in engineering methods made in other industries because it hasnâ&#x20AC;&#x2122;t needed to. It is only with the increased technical demands of modern operations that the necessity to improve the approach becomes apparent. It is generally the smaller and younger companies that need to differentiate themselves by adopting the latest technologies and be ever more innovative in the way they approach their work, that lead the push. This provides opportunities for companies like Engenya GmbH to offer highly specialized services and innovative products to those wanting to gain a competitive advantage. Services typically offered range from engineering analysis for the purposes of risk mitigation, tool integrity and performance evaluation, design audit and support, and failure analysis, to complete system development including tool design, testing and qualification. Projects almost always require a

A comparison between measured and simulated strains in a down hole tool test. multidisciplinary understanding and approach, and the breadth of experience and depth of technical knowledge on offer is a reassuring element for any client. The value and the high level of insight which can be gained through the use of modern engineering analysis methods can be best illustrated through some concrete examples.

within the gun stringâ&#x20AC;&#x2122;s perforation interval. The data was then used to calibrate simulation parameters so that a reliable fluid and structural dynamic response could be calculated for any job for the purpose of identifying failure risk before actually running anything into the well. The tool has successfully demonstrated its versatility in improving gun and tool string

Redefining tool design via real-time measurement systems and state-of-the-art simulation

To develop more robust tool strings and avoid failure a client sought to understand the true well fluid and tool string dynamics in response to the detonation of perforation charges. This led to the development of a simulation tool as well as a data logging sub to retrieve previously un-captured data aimed specifically at supporting the validation of simulation results. To do this, the sub had to be developed to be able to measure and record a number of environment variables from

A study of a shaped charge detonation using advanced meshless methods

design, as well as explaining seemingly arbitrary failures in the field. Furthermore, the data logging sub is now being used to provide real-time, high-speed measurements of underbalance in new wells.

“

Projects almost always require a multidisciplinary understanding and approach, and the breadth of experience and depth of technical knowledge on offer is a reassuring element for any client.

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Slowing down formation flow

time

optimize

State-of the art simulation techniques have also been used to guide the development a novel gun system in order to maximize formation flow. The client’s prototype gun system showed counter intuitive behaviour that could not be explained. A detailed simulation of the test was able to provide insight into the dynamics of the system by effectively allowing the system response to be scrutinized in slow motion – something that usually cannot be done in tests involving explosive tools. Innovative charge configurations are now being employed in pre-production tests.

strings for new fields being developed by a client, with the specific goal of reducing technical risk before any steelwork is actually put in place. Engenya’s work proves that prevention is better than cure, indicating that engineers are starting to embrace the necessity for change.

Finite element mesh of mechanical subsystem in field tool design There is no doubt that extracting oil from the Earth is going to become increasingly difficult while the demand for it, as well as the opposition to it, continue to rise in the foreseeable future. To meet this demand while satisfying all of the ancillary social and environmental requirements means that in the long run there is no choice but to continue to improve how things are done. Written by Engenya GmbH Consulting Engineers. Photo and figure credits: Engenya GmbH, Halliburton Energy Services & Starboard Innovations. A model for the study of gun wall perforation combining different meshing approaches

Advanced virtual diagnostics and s.o.p enhancement The understanding of field failures has also seen the benefit of advanced engineering technologies. In one case, an apparent malfunction of a firing head had ruined a well and led to a substantial recovery cost and questions about the validity of the tool design. Through a structured failure analysis that included material characterization, system simulation and validation testing, it was shown that the design was sound. A thorough evaluation of sensitivity to changing design parameters was then possible through simulation of validated models, putting the client in a position to demonstrate that the failure could not be ascribed to the tool design. More importantly, the added insight enabled a revision of procedures to avoid re-occurrences of this problem. These are only a few examples of the many projects Engenya GmbH has worked on where the value of its engineering methods, common in many other industries, was proven and is continuing to do so with an ever-expanding list of companies. Engenya is currently involved in the evaluation and design of production

Engenya’s client list in the Oil and Gas field includes companies like Premier Oil, Halliburton, Delphian Ballistics, DynaEnergetics and Starboard Innovations. Engenya GmbH operates out of Winterthur, Switzerland but is also present in North America, Italy and South Africa. . Queries can be directed to: Andrea Serra Director of Business Development Engenya GmbH Landvogt-Waser-Strasse 65 8405 Winterthur Switzerland Tel.: +41 52 202 4104 Email: info@engenya.com Web: www.engenya.com

Unlocking Engineering Solutions for the Oil & Gas Industry

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Schlumberger Launches Industry-First Photorealistic Reservoir Geology Service Schlumberger launched the Quanta Geo photorealistic reservoir geology service at the Offshore Northern Seas Annual Conference and Exhibition. The new service includes the industry’s first microresistivity imager that produces oriented, photorealistic, core-like images of the formation in wells drilled with oil-base mud (OBM). Interpretation of the images identifies geological features and predicts reservoir trends in 3D with a high degree of certainty. “Geological imaging in wells drilled with OBM has long been recognized by operators as a major technical challenge, particularly in deepwater,” said Hinda Gharbi, president, Wireline, Schlumberger. “The Quanta Geo service provides photorealistic images that can be used to condition and constrain reservoir models, enabling our customers to better understand their reservoirs and make decisions with more confidence.”  The physics of the Quanta Geo service’s high-resolution array of 192 microelectrodes overcomes the electrically resistive barrier imposed by OBM. The unique articulated caliper and independently applied pads enable down-logging at up to 3,600 ft/hour, which significantly reduces rig time while mitigating operational risk and delivering data assurance. The service is combinable with most other Schlumberger wireline openhole tools. Using the Schlumberger Techlog wellbore software platform, data, acquired by the Quanta Geo service, is easily rendered, creating an image of 0.24 in resolution that resembles a whole core. Geologists interpret these images in the same manner that they would perform continuous core description, with the added benefit that these images cover a longer continuous interval and are precisely oriented. This enables extraction of key reservoir parameters such as the structural dip, or the identification of sand body type, extent and orientation. The Quanta Geo service has been field tested in more than 50 wells in deepwater, unconventional and carbonate environments in the Gulf of Mexico, West Quanta Geo service’s photorealistic images enable a visual interpretation of subsurface geology Africa, North Sea, North America and Australia. In the Gulf of Mexico, a customer drilled a deepwater exploration well in an area of limited seismic resolution. Images were acquired with the Quanta Geo service to address large uncertainties related to the type and distribution of sand bodies intersected by the well. For the first time in an OBM environment, the customer was able to visually categorize the various sands and directly measure their orientation. This information was used to refine the geological model and define the field appraisal strategy. Quanta Geo service is the inaugural member of the new Quanta Family reservoir characterization services, which employ new measurement physics to deliver highest accuracy, workflow-ready downhole measurements for direct use in refining reservoir models.

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The Latest Market Trends in the Equipping of Offshore Vessels with the Newest Technologies EMC, Europe Marine Control is a system integrator who designs, produces and delivers turnkey complete electrical installations and equipment (drive systems) for offshore vessels. The company has been operating in the offshore market since the 1980â&#x20AC;&#x2122;s. EMC is unique in its approach to projects and its large scope of supply.

he electrical scope of shipbuilding projects is often seen as consisting of a few switchboards, desks and an alarm system. Traditionally, shipbuilding meant using conventional technologies and processes due to their proven reliability. However, rising fuel prices, stricter emission regulations and higher levels of automation requirements are pushing the sector to catch up to new technologies. What are the latest trends in our market?

ensures the operating load is at the fuel - and emissions efficiency optimum. When vessels have different purposes, a combination of diesel-electric and diesel-direct propulsion can be the best solution. In hybrid mode, the vessel propulsion and power plant can be configured by the operator to meet the vessels operation mode within certain fuel- and emissions restrictions. Due to more configurations now being available, the deploy-ability of the vessel has been increased.

Integration Level 1: Power and Propulsion Systems

Fuel reduction for conventional power plant

Hybrid power and propulsion By knowing the vessels operational profile, the machine package can be sized in a way that

Fuel costs represent a large amount of the overall operating cost. For the offshore market, most of the vessels are dynamic positioned (DP). Besides keeping the vessel on position,

the DP system also needs to offer a certain grade of reliability depending on the DP class. Different vessel power-plant-propulsionconfigurations are available to ensure the vessel achieves its required grade of reliability. These configurations, however, are not the most fuelefficient systems. When operating a vessel switchboard with an open busbar, for example, a minimum of four generators is needed online in DP mode (2 on each side). In calm seas, the required load will be very low, and the generators will consume unnecessary fuel and accumulate unnecessary running hours. One of the options EMC offers is to install a special ultra fast bustie breaker. With this

breaker, DP can be operated with a closed bustie and the amount of generators can be reduced without compromising its reliability. In case of a short circuit the bustie will open before the other side of the switchboard is affected, in this way not sacrificing its reliability.

EMC, however, is using a data collection system, parallel to the alarm monitoring system. This data collection is based on internet protocol (IP). IP data collecting is a much faster and more efficient way of acquiring this data than using PLC’s, especially regarding the design, the commissioning and the vessel maintenance. This system consists of a backbone running through the vessel. On various points there are data collection boxes. Any equipment with an Ethernet connection can be connected to the backbone using Cat-6 internet cables. By deciding on equipment with an Ethernet interface, it can easily be connected to from anywhere and new applications can be created remotely. Initial benefits of this system are: •

Reducing the number and types of cables needed

•

Large amounts of data can be sent

•

Any equipment with an Ethernet port can be connected

DC-busbar systems An upcoming technology is the DC-bus bar. With new DC components available in today’s market, it is now possible to replace the main 690V and 440V by a 960V DC switchboard. As many consumers as possible will be connected to the DC-busbar to reduce energy losses. The system makes it possible to reduce the speed of the generators to the fuel optimum at any given load. Reducing diesel-generator speed will lower fuel consumption and reduce required maintenance. This technology can be applied to a conventional setup as well as hybrid propulsion plants.

What are we currently using it for? •

Telephone system. The IP telephones connect direct to the backbone

•

V-sat/Fleet broadband. Connecting these systems enables internet and telephone communication throughout the vessel

•

Seatel/TVRO. Bringing channels in to the system

•

Entertainment. On-demand movies and TV can be played on the vessels, much like the systems installed on many airplanes. This content be viewed on a television, laptops and mobile devices

•

Computer network. For administration and for entertainment of the crew

•

Remote monitoring of ship equipment. The super intendant can receive data of the ship systems.

Integration Level 2: Data, Computer, Entertainment and Remote Monitoring Since today’s vessel operators have higher requests on monitoring individual parameters and systems, more information needs to be collected. Traditionally, the alarm monitoring and control system was used to do this. These systems were created for mechanical equipment and designed to read the status of sensors.

television

ship the

•

Shore-based maintenance. By allowing OEMs to access the systems remotely, they can trouble-shoot these devices and update their software

Integration Level 3: The Client and EMC, the Crucial Step Selling the equipment and engineering services is step one, but how to make it work? At EMC we consider this a mutual responsibility and we therefore work together with the client until the vessel fits all the requirements, is approved by appropriate associations and accepted by the operator. We have a diverse group of clients with different needs. They will know to contact us for our expertise on system integration. After selecting the main equipment, the detailed engineering and construction starts. From this phase, EMC will adapt their work process to complement the client’s organization. This can mean an engineer will be stationed at the office of the client for better communication or logistics will be arranged on site. In each step EMC will assist the client’s needs, leveraging both companies’ expertise. Not all organizations need the same support; therefore we distinguish the following categories: •

Essential integration; Power plant, propulsion, automation and commissioning

•

Medium Integration; Power plant, propulsion, automation, electrical systems and commissioning

•

Full integration; Power plant, propulsion, automation, electrical systems, mechanical, site supervision, logistic support for construction and commissioning

How do we do it? EMC has a strong base of highly experienced people with multidisciplinary skills. A small core team will be involved in the project from start to finish, assisted by different specialists in each stage of the project. We ensure there is no loss of information or quality because the client deals directly with the people responsible for the project. By using the same people throughout the whole process from start to finish, we can ensure a seamless progression of the project with focus on the best technical solution, high quality and shortest delivery time.

EMC, Europe Marine Control BV Het Vergun 6 6931 KD Westervoort, The Netherlands +31 26 319 50 60 info@emcmarinecontrol.com www.emcmarinecontrol.com

UNDERSTAND COMPLEX PROCESSES AND REDUCE COSTLY TRIAL AND ERROR EXPERIMENTS WITH THE UNSCRAMBLER速 X!

Multivariate analysis (MVA) is widely used in the oil and gas sector for i.e. performance prediction, outlier identification, understanding complex processes, planning maintenance and forecasting. Some areas of application include:

Classification of geological formations Detection of out-of-control situations during production Production allocation Environmental monitoring Find out more

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sales@camo.com www.camo.com

E & P: PROJECT MANAGEMENT

Project Management is Key to Any Major Offshore, Marine or Oil and Gas Operation, And Not Only For Keeping Budget... We Interview Nordhagen Management AS to Investigate. OGIâ&#x20AC;&#x2122;s Emma Patten sits down with Nordhagen Management AS CEO, Jonny Olsen to discuss the benefits to operators, shipbuilders and EPC Contractors in various sectors using good proven project management software and services not only to stay on budget during massive operations, but also to make sure HSE guidelines are being strictly followed and workplace safety is of utmost importance.

Emma: To start off could you explain how Nordhagen Management and Nordhagen Projects help companies in the offshore, maritime and oil and gas industries? Could you explain the breadth of your experience, such as your noted works with the likes of BP, Aker and Transocean? Olsen: Nordhagen Group, which consists of Nordhagen Projects AS located in Bergen (Norway), Nordhagen Management in Stavanger (Norway) and Nordhagen Projects Ltd in Aberdeen (UK), provides a customizable total project management solution, which helps our Customers to reach their goals within safety, cost, time and performance. This is achieved by our expert project teams together with our proven project management system, N`PAS. We can deliver total project management as well as an integrated project management team together with our Jonny Olsen, CEO Nordhagen Management AS Customers own people. Our software N`PAS, coupled with our best case processes and procedures, gives a total project management package which maximizes cost efficiency and de-risks project work scope, through robust project planning, leading to effective project execution. We use a slogan to illustrate this: “our contribution, your success”. Nordhagen Group offers predictability, structure and speed. We have a proven track record with more than a decade of project management experience. All of our project work as well as processes and procedures are certified and according to DNV ISO 21500 and ISO 9001. We work very close with our valued Customers, such as Transocean, Songa Offshore, Odfjell Drilling, BP, Prosafe, Maracc / Island Drilling and Aker. Nordhagen has a frame agreement with Transocean and have managed and participated in every project in Transocean Norway since 2006 providing our expert project teams and our project management system N`PAS. Project management is key

Emma: Could you explain to our readers why it’s so important for Oil and Gas / Maritime companies to utilize various project management products and services? Olsen: Project planning and execution on an out of service project is not normally part of our Customer’s core business. Rig owners and oil companies core business is drilling and E&P activities in normal operation. When a rig / drillship is going out of services for Class activities, upgrades or modification, these are activities that have to be done but are not part of the Customers core business activities. The rig owners and oil companies normally just want the project completed according to budget and plan, so they can get back to normal operating business. This is when project management experts like Nordhagen Group come in and help our Customers to achieve their goals, and get the rig or drill ship back in service as soon as possible, with zero incidents and within the budget and plan. This is our core business, our niche and our speciality. By utilizing our project management system and expert teams we optimize the

planning and execution, and save significant time and cost on behalf of our Customers. Emma: There are many approaches to project management. Traditional approaches spring to mind such as the traditional phased approach, lean project management and critical chain to name a few. What approach(s) does Nordhagen use in most cases for Oil and Gas or Maritime clients? And what products do you employ to achieve the desired results for your clients? Olsen: There are many theories around project management. Our main approach is based on performing a comprehensive package of procedures, that are reviewed and approved by the Project Stakeholders, and sanctioned by a best case Stage Gate / Decision Gate process management. Our processes and procedures are approved and certified according to DNV ISO 21500 and have been thoroughly tested. Our proven track record based on this approach, as well as our experience with several Customers working with a similar approach, gives a solid foundation when introducing our project management solution.

By utilizing our approach, we optimize planning and execution, secure the right stakeholder involvement and approvals, and ensure that all levels of Customer management, project governance and project execution are well taken care off. A project well planned is a project well executed. We use our project management system N`PAS to achieve and improve the desired result for our Customers. N`PAS is a complete project management system which includes, administration of work orders, budgeting, a very good cost control module including electronic import of man-hours and cost, work packages, documentation, planning, historical data and notes, variation order control, check lists, more than 100 predefined reports and other functionality. The system has a proven track record and our Customers are very satisfied with the system. Emma: From our own investigative surveys, we found one constant with EPC contractors and shipbuilders who read our publication. They all put a premium on maintaining cost during their project. In terms of the complete life cycle of project execution, what strategies, products and services does Nordhagen employ to maintain a client’s cost efficiency? Olsen: Nordhagen Group has extremely high focus on cost during project planning and execution. Our principle is that “every coin counts”. Cost efficiency and saving money on behalf of our Customer is one of our key success factors. A strict cost control, especially related to Time and Material scope of works, good variation order control and procedure, and strict cost discipline throughout the whole project team is crucial to succeed. Additionally, identification and mitigation of risk is an integral part of the project planning process that our project management solution utilizes, and risk is tracked and reported throughout the project. To manage this we use our project management system N`PAS to plan, monitor and execute all aspects of the project. The system is tailor made and revised over more than a decade of projects to get a best possible cost effective project. We are proud that our Customers share our passion for this software and processes. Furthermore, our experienced personnel are of course a key to succeed in the projects. Our concept is to run projects with a combination of committed and expert personnel and a field proven project management system. All our personnel are thoroughly trained and experienced with our best case stage gate process management. Emma: Another constant with most companies that we speak to is the huge importance of health and safety in project execution. What is Nordhagen’s stance on matters relating to Health, Safety and Environment for project management? “Nordhagen Group has a long-standing HSE commitment..”

The N’PAS system Olsen: The most important objective of Nordhagen Group is to prevent accidents, injuries or losses. Health, safety and environment is crucial, and one of the most important aspects of a project. Our project philosophy is a “zero” tolerance when it comes to HSE. We strive to deliver projects within plan and budget, and without any incidents at all. Nordhagen Group has a long-standing HSE commitment to the highest standards for the health and safety for our employees, Customers, contractors and equipment as well as to the protection of the environment in the communities in which we live and work. We have experienced personnel and processes who live and breathe the HSE standards. This is incorporated in everything we do, and we will never take any short-cuts or simple solutions that could jeopardize health, safety or environment. It doesn’t help to deliver a project on budget and plan, if you have any incidents. Or system N`PAS also has a separate risk module for risk assessments and mitigating actions which follows each scope of work throughout the whole project and an integral part of the risk calculation includes assessment and mitigation of risk relating to HSE. Emma: Finally, could you enlighten my readers with a possible case study or scenario where Nordhagen AS helped a client improve safety, maintain budgeted costs and ultimately improved efficiency in the clients project execution using your software, such as N’PAS? Olsen: We have several examples and documented results where we improved safety, maintained or delivered the project even below the budget and improved efficiency. We are proud that our clients are satisfied with

the performance and execution of our system N`PAS and our project expert teams. We have documented cost savings on behalf of our clients in most projects in the region between NOK 20 – 50 millions. Several project have been delivered before scheduled plan, and we have a good QHSE records on our projects. One example is the statement from CEO of Maracc / Island Drilling: “The personnel from Nordhagen introduced speed and structure to the project. They were organized in an efficient and cost effective way. This greatly contributed to a successful result”. Additionally, the long standing relationship with Transocean in Norway, where we have been involved in every one of their major projects since 2006, gives us a great sense of accomplishment and pride, and recognition that our project management solution adds value for our customer time after time. This interview was conducted by Oil and Gas Innovation’s Emma Patten - Investigative Journalist and Nordhagen Management AS’s Jonny Olsen - CEO. For more information or to find out how Nordhagen Management AS can help your projects contact Mr Olsen at: +47 91 91 22 88 or via email at: jonny@nmanagement.no or on the web: www.nordhagenprojects.no

E&P

Producing Air Compressors that Meet the Demands of Today’s Industry Granzow A/S has been providing Industrial Solutions since 1935 and we are one of Denmark’s leading specialists for the industry’s screw compressors. We also produce solutions for automation products, such as bursting discs and panels, valves and pneumatic cylinders. Additionally, Granzow has an extensive offer of pumps and a complete line of vacuum pumps.

n the past twelve years, The Danish company Granzow AS has delivered many Instrument Air Compressors & Dryer Packages for the offshore industry in accordance with both ATEX regulations, Zone II and Zone I. The first deliveries were placed in the Safe Area (which means air compressors with minor electrical and mechanical changes in the design) of the different standard air compressor units. A small number of the packages were designed to fulfill the Eexd norms. A small part of the package is where seawater cooled, which often gave a shorter lifetime to different components in the compressors package. The greatest benefit to the customer in this instance, was their design was designed to be cooled with fresh water, with heat dissipation in the radiator system and radiators mounted in the hazardous area. A further advantage of using fresh watercooling is the decrease in ventilation flow through the compressor unit, which gives the user a lower spare parts consumption rate. The radiators were the most technically challenging unit in the package, as they have to face corrosion, a problem which was solved by using Titanium frames and piping with cooling fans in S316 motors, all of which had the proper certification for the hazardous areas. Today this is ATEX certification.

be constructed and produced too, and what documentation is needed for the acceptance of the entire package. When air compressor units have to be installed in hazardous areas, they must be classified by gas groups and zones: •

Zones are used to define the probability of the presence of flammable materials

•

Groups classify the exact flammable nature of the material

•

Protection is used to denote the level of safety for the device used

•

Approval is needed on Pressurerised receivers, temperature classes, for example: from T1 to T6

When delivering compressors today, we have to make sure that the certification includes all the required documentation on air compressors units in ZONE II, Gas IIA, T3. If the project demands the control and starter panels of the unit, these will be in accordance with ZONE I. Examples of critical demands are the mechanical ATEX part, a suction system filter, regulator and separator (for separation of oil from the warm compressed air and oil filter). Every component must be certified for the acceptance and the approval of the total package before the air compressors can leave the manufacturer’s factory. The first step of designing a package is to agree on the production of the unit, what standard the air compressor packages have to

A typical radiator with ATEX certification

The document for European production of units is always followed with the words “EC declaration of Conformity”, stating for example: ATEX1994/94/EC EX II 3 G IIA T1 for this application.

“

Delivering compressors today, we have to make sure that the certification includes all the required documentation on air compressors units in ZONE II, Gas IIA, T3. The proper certification for the hazardous areas is the ATEX certificate.

”

The best result for a project will always be a “kick of meeting” where all aspects of the project are on the agenda for the meeting. Aditionally, third parties have to be involved in the meeting, as they are an essential part under the FAT, in the makers test bed. The air compressor (pictured left), with 75 kW electric motor, is air cooled with a fan flow up to 14000 m3/h. The control panel shown on the unit is ZONE I. Alternatively the control and starter panels can be mounted in the Safe Area, which will bring down both the cost and the electrical documentation needed.

An air compressor with ATEX certificate, Gas IIA, T3

The dryers that are normally included in the package are normal adsorption dryers with a heatless design and a dew point controlled to -40 °C at line pressure. These dryers are designed to the mentioned dew point and not to a dew point level of, for example -20 °C, as the adsorption desiccant quantity will always dry the flow of air to the -40 °C. Adsorption dryers, designed with regeneration using heating elements and about 3% of dry air, bring the cost of the dryers to a very high level, if the dryers have to run in a hazardous area. The heating elements inside the dryer normally work up to the temperature of 160 °C, under Regeneration – this can bring the dryer vessel surface temperature up to more than the 160 °C, if there is free water in the compressed air running into the dryer. This is why offshore companies generally prefer heatless dryers. Our experience from the different projects we have been working on, have completed and/or commissioned, have resulted in our gaining the documentation “SDRL” demand. The production of ATEX compressors in Europe is always supported by valid legal documents, which are approved by different authorities. The production itself is approved to ISO norms, which are accredited every

year by a third party. Everything should be in accordance with a quality level which secures the end user a reliable compressor unit. Different international consulting engineer companies normally have their own design parameters, which are not always in line with the makers’. This can be the most difficult part of a project, as this brings on the discussion of the meaning of a particular document. We recommend solving this matter before any production takes place.

“

The production of ATEX compressors in Europe is always supported by valid legal documents, which are approved by different authorities. Everything should be in accordance with a high quality level which secures the end user a reliable compressor unit.

”

Granzow can also provide Bursting Panels solutions for the protection of dust explosions for personnel and equipment. These panels

are manufactured as individual applications. The pressure is set between 0.017 bar and 0.35 bar. All material and certificates are included. Air-operated diaphragm pumps represent another area of core competencies. The wide range of materials permit the rating of the pumps to meet individual requirements and can be made to convey any media. Their main advantage is high efficiency and the suitability to use in potentially explosive and hazardous applications.

Granzow A/S Ejby Industrivej 26, 2600 Glostrup Copenhagen www.granzow.dk info@granzow.dk

E&P

Manufacturing Low Friction Fluoroglide Skidway Plates and Bearings Manufacturing and supplying slide bearings for more than 50 years, Fluorocarbon’s bearings are based on Fluorogold technology from the original Fluorocarbon USA company. During the last 40 years Fluorocarbon UK has developed the product and applications for two different markets, offshore and onshore.

luorocarbon developed a Fluoroglide skidway system for the load out of the BP Fortes jacket at McDermotts Scottish construction yard in 1986. Since this success Fluorocarbon has continuously developed and improved the concept with additional products and services to reduce load-out friction. Due to changing tides and barge/crane availability engineers often only have one chance or window to ensure the skidding operation of a large structure is successful. Fluorocarbon is proud of a 100% successful load-out record, in this way ensuring first time load-out with low coefficient of friction, which saves the construction yard additional costs normally associated with extra pulling force required with higher load-out friction. Skidding large offshore fabrications on a PTFE skidway is now the accepted standard for structures heavier than 5000 tons. The standard for PTFE skidways is specified worldwide, these skidways being used in conjunction with Timber skid-shoes to ensure a coefficient of friction less than 10%. Fluoroglide skidway systems incorporating PTFE technology are now used around the world. The Liwan process platform fabricated by COOEC weighing 33000 tons was recently successfully loaded out on a Fluoroglide skidway system achieving Dynamic friction values of less than 5%. Along with on site consultancy, Fluorocarbon offers a range of products to complement our skidway systems, in this way ensuring we offer the best systems for successful load-outs with a low coefficient of friction including lubricating systems, reduced break out membrane and timber skid shoes. The offshore market for Fluoroglide Fluorinoid bearing systems can be broken down into 3 market segments: •

Skidding of Jackets and process decks on to the transportation barges ready for load-out

• •

Bearings for pipe and pedestrian bridges between jackets Subsea slide bearings for PLETS and Sleeper foundations

Fluoroglide bearings can be manufactured to a particular specification for use in the aggressive marine environment such as platform bridge bearings between jackets or flare stacks. There is a requirement for slide bearings in high temperature environments

Jacket load out under flare stacks, which is why, for these applications, Fluorocarbon has a range of slide bearings utilising graphite as the sliding face. The Technology for the complete range of Fluoroglide Fluorinoid bearings is based on PTFE, originally developed by DuPont. The coefficient of friction values, for slide bearings published 70 years ago, is 0.06 for a typical bearing pressure of 70kgs/cm2. Fluorocarbon has verified these internally and from

independent test-houses, confirming that the Fluorinoid range of virgin and filled PTFE has a coefficient of friction values of 0.06 or, in many cases, lower. The manufacturing of Fluoroglide slide bearings and skidway plates has been developed over many years. To guarantee a successful load-out with low coefficient of friction, it is essential to have a series of quality control checks in place at each stage of manufacture. These include: •

Fluorinoid Special grades of virgin and filled (reinforced) PTFE

•

Choice of protective corrosion resistant coating on exposed metallic surfaces

•

Daily pre-treatment of the metallic

A graph of friction for timber skid shoes against fluorinoid PTFE

Subsea Applications The growth of the offshore subsea market has resulted in the requirement for a range of PTFE slide bearings, which will continue to function at depths of up to 2000 meters for many years.

“

To guarantee a successful load-out with low coefficient of friction, it is essential to have a series of quality control checks in place at each stage of manufacture.

Fluorocarbon skidway plates

”

Special grades of PTFE, which satisfy the requirements to operate well in subsea, have been developed by Fluorocarbon. The Fluorinoid grades, however, do not support growth of marine life, which is essential for long life subsea. The evaluation of the Fluorocarbon ‘J’ Bearings was undertaken by the UK’s engineering research centre in conjunction with BP to measure wear and friction in full size test rig using sea water at 2oC. Having passed these tests and be declared up to a certain standard, the large number of bearings have been in service for more than 10 years in deep water, offshore Angola. backing plates ready for controlled bonding •

Choice of Epoxy bonding systems to suit environment, temperature etc.

•

Choice of protective corrosion resistant metals and coatings

A range of Sleeper pad ‘T’ Bearings has also been developed using alternative polymeric materials for specific subsea applications. Once again, all products have been wear and life tested in seawater containing sand particles. The ‘J’ and ‘T’ bearing systems have been specified by McDermott for the flow line and production lines PLET and Sleeper pads for the INPEX ICHTHYS project 900 KM long subsea pipeline in Australian waters.

The failure of PTFE skidway plate, manufactured by a local yard with poor materials and technology Fluorocarbon engineers are available to discuss Fluoroglide bearing use at all stages of a project, in many cases producing bearings within 24 hours for urgent requirements.

Fluorocarbon Ltd For more information please contact: Tom Savage/John Steel +44 (0)1992 526837 oilandgas@fluorocarbon.co.uk www.fluorocarbon.co.uk

MIDSTREAM & PIPELINES

Northwestern Support Professionals Inc. Explains to OGI Readers the Importance of Automating Your Pipe-Yard Inventory Management Process A busy Canadian pipe yard loads and offloads as much as 50,000 metres of pipe every day, representing about $2.5 million in inventory. Rather than having to perform tallies manually, software solutions like Tallys and TallyWizard are quickly becoming the standard for inventory tracking and management among leading companies in Canadian oilfields. OCTG Inventory Management

or a small team, managing high volumes of inventory can be daunting. Many still perform tallies manually; incoming and outgoing shipments are entered into a spreadsheet or local database by dispatchers and yard staff. Jason Newman, VP at T Bar 1 Transport, explains the complicated system of excel spreadsheets they were using to manage inventory. According to Jason, it was less than perfect: “Tubing would get delivered, so we’d write it in the dispatch book. Then the joints would need to go on the rack and be counted, tallied. Then we’d bring that count in and enter it into the excel system we built. We’d have to enter it manually every time. Then when joints left the yard, we’d have another sheet where we marked outgoing joints. We always had to remember that when we added a record to the outgoing sheet, we’d have to remove those joints from the inventory sheet. It was a lot of work. With that old system, there was just so much room for error. In the end, we created a third sheet, to mark down every job that happened, so if all of a sudden something was missing, we had a third one to back check on. Then we had someone in the back office checking for errors. There was a lot of manual checking and adding. A lot of room for mistakes.” Ian McKinley is VP of pipe inventory and OCTG products at Winalta Transport Ltd., a division of TFI Transport 7LP. Winalta also entered the field with the idea of tracking tallies manually - using spreadsheets and database programs like Lotus, and Quattro pro. According to Ian, tracking tubular goods on a spreadsheet was labour intensive and error-prone: “Any time you’re dealing with data entry, there’s room for error. If you’re building a spreadsheet with tallies in and tallies out,

you’re trying to copy and paste and manipulate [the data]. When you don’t own the product, and you’re managing it for someone else, you need to be 100% accurate.” Darcy Paulson is the pipe yard and inventory manager for V.D.M. Trucking Services Ltd. When he joined the team in 1998, they didn’t even have a pipe yard. But for a company that wanted to continue to grow and stay competitive, adding a pipe yard was the next logical step.

“

With their first yard, a four-acre plot in Edmonton, Alberta, the company was tracking tallies with a calculator, recording the information manually. It’s a process Darcy admits wasn’t sustainable in the long term: “With the size we are now, there’s no way we could be tracking inventory with a manual system. You need a program [to do the tallies].”

“

Any time you’re dealing with data entry, there’s room for error. When you don’t own the product, and you’re managing it for someone else, you need to be 100% accurate.

”

Automated inventory management The Tallys system was initially deployed in 1993, developed by Pelican Software. In 2011, development of Tallys was taken over by Northwestern Support Professionals Inc. According to Craig Reimer, Director of Technical Operations at Tallys, managing OCTG inventory is a matter of speaking the language commonly used in the field, something Tallys has been working on for

more than two decades. “Having the right field references is key to inter-business communication and integration. A regular accounting program might have an “item description”, sku, or part number, but may not have a place to store “Size”, “Wall”, “Weight”, or “Thread”. Each of these, even terms like “Yard” and “Rig” are important when giving context to a shipment of OCTG. Other POS and inventory handling solutions tend to have broad terminology to accommodate to a larger market. Those systems hold less value for people in the OCTG industry, that is, they leave room for error when managers are forced to assume which reference is tied to a given field. Anyone managing their tubular inventory with some level of precision will appreciate a system that breaks everything down in terms they’re comfortable with. So we’ve remained focused on a single, vertical market, instead of reaching out horizontally, because that’s what continues to work for our clients in the field.” EVRAZ (formerly Ipsco) reached out to the Tallys team back in 2000, asking for help in making their proprietary OCTG definitions and transactional criteria a requirement when managing EVRAZ stock within Tallys. What resulted was an EVRAZ specific validation process. To this day, EVRAZ maintains a spreadsheet of pipe sizes, walls, weights, threads and grades. When pipe descriptors are added or changed, Tallys users simply read the updated file from EVRAZ’ server to make the latest definitions available. For companies like V.D.M Trucking, the integration with industry leaders like EVRAZ made the decision to start using an inventory management system like Tallys simple. “When we started tracking EVRAZ pipe, they (EVRAZ) asked us to start using Tallys as well. Once we started using it, it was good, it

made everything easier. Instead of adding everything up individually, we could just type in how many metres we needed and Tallys would figure it out.”

Eliminating errors leads to increased efficiency Even with checks and balances in place to ensure accuracy, using a manual tracking method for OCTG inventory isn’t ideal. Jason Newman talks about the difference automated inventory management made in their day-to-day operations. “[Working] with Tallys, it allowed us to have a system where, once you have the name of the company you’re sending joints out to or getting joints from, it does all the work for you. Tallys helped us, because it shortened the amount of time we had to spend on entering things into the system, so it increased our efficiency, and there were way fewer mistakes. It was a really beneficial thing. Before Tallys, we were probably spending an hour every day checking for errors. Every transaction was taking 2 minutes. With Tallys, we’ve cut that time in half, and we’re not spending any time checking for errors. It’s hard to put a number on the savings, but it’s pretty significant.” In 2013, T Bar 1 Transport was named Lloydminster’s Business of the Year. Jason attributes the award to the company’s service record, and their increased efficiency. “People like to deal with us because of our customer service and efficiency. They get their pipe on time, they get it at a reasonable price, and they get to deal with good people.” According to Ian McKinley, adopting an automated inventory management systems has eliminated 100% of errors. “100% accuracy isn’t an exaggeration. We have no errors. Zero errors. 100% audits. We audit the yard probably 6 different times throughout the year, and we’re consistently 100%. The only time we have a mistake is from human error, Tallys does not make any mistakes.”

A busy Canadian pipe yard loads and offloads as much as 50,000 metres of pipe every day.

“

Anyone managing their tubular inventory with some level of precision will appreciate a system that breaks everything down in terms they’re comfortable with.

”

exciting. Over the last five years, dumping of OCTG sold below cost to the North American market has driven prices down in the domestic market. The recent anti-dumping rules imposed by the USITC (international trade commission) represent renewed opportunities for pipe and steel mills in Canada and the United States.

An industry on the move

different lot numbers, different volumes, different pipe. You need to be able to manipulate the software to each one of those clients, and run the business to match those clients.

More initiatives in Canada, and a US goal of becoming energy independent by 2020, all mean more opportunities for pipe yards, manufacturers, everyone in the OCTG industry.

Digital communication tools continue to guide the direction of the OCTG industry. Clients expect real-time communication and reporting regardless of location. Security and accuracy are major milestones in the ongoing development of inventory management systems.

What anybody can learn to do, is to make the software work for them. As the business grows, the software grows with you, and you develop shortcuts to let the software do your job easier. When you’re handling tubular goods, data entry is the key element. We’ve advanced to the point where we never data enter anything everything we do is done electronically.”

We’ve done very well in the Canadian market, and we’re excited to be able to serve the US market in the same way.”

Ian talks about Winalta and Tallys’ relationship over the years, pointing out that each was instrumental in shaping the growth and development of the other. “We’re talking about 9, 10 years of development. Our business has grown, and our yard has grown, and we could be managing 5, 6 clients at any one time, and we’re entering

Craig Reimer has some ideas about the future of inventory management in the OCTG industry. “US spending on upstream exploration and production is up 8.5% in 2014 over the previous year, and Canada is showing growth around 4.5%. The growth in exploration and production means growth in OCTG, which is

Northwestern Support Professionals Inc. +1 877 661 9990 (toll free) simon@nwsp.ca www.nwsp.ca

European Autumn Gas Conference Grange St Paul’s Hotel London UK 28 - 30 October 2014

EUROPE’S PREMIER EVENT FOR SENIOR GAS PROFESSIONALS 2014 Conference Programme Highlights: Trading, Finance & Investment In Gas: Is There Anything Left in Europe – or Shall We All Just Move to Asia…? Global Market Outlook: Has the Context of European Security of Supply Totally Changed? Supplier Strategies: What are the Choices for Europe, and Where Will Supply Come From? Focus on LNG: All Eyes on LNG: Will Europe Remain a Key Global LNG Market? Policy & Regulation: An Audience With… the Politicians and the Regulators Demand-Side Innovation: The Changing Face of Gas Use in Europe Confirmed speakers include: Marco Alverà, Chief Midstream Officer, Eni

Julio Castro, Head of Global Gas & Trading and Origination, Iberdrola

Stephen Asplin, Chief Commercial Officer, Power & Gas, E.ON Global Commodities SE

Jogchum Brinksma, Managing Director, Citigroup Global Commodities

To find out more about delegate participation, please contact Laurence Allen, Marketing Manager at laurenceallen@dmgevents.com or call +44(0) 203 615 0390 www.theeagc.com Gold Sponsor:

Silver Sponsors:

Bronze Sponsors:

Associate Sponsor:

China Orders Oil Firms to Fix Faulty Pipelines Within 3 Years

Reporting by Judy Hua and David Stanway; Editing by Muralikumar Anantharaman

China has ordered oil firms to fix faults in their oil and gas pipeline networks within three years, Sinopec Corp said on Thursday, almost a year after a blast in the state-run refiner’s pipeline killed 62 people. This is the first time a deadline has been imposed on oil firms to rectify the long-standing safety problems in their pipelines, which could increase the costs to deliver oil and gas. China uncovered nearly 30,000 risks in its oil and gas pipeline sector during a nationwide safety probe launched at the end of 2013, Sinopec quoted a notice from the State Administration of Work Safety as saying. The administration called for accelerating rectification in the oil and gas pipeline sector and making efforts to complete fixing the problems by June 2017, Sinopec said on its website (www.sinopecnews.com). The State Administration of Work Safety, an agency directly under China’s State Council and responsible for safety regulation in the country, could not be immediately contacted. Sinopec said the State Council, or cabinet, will set up an institute guiding Part of a corroded oil pipe the rectification work. National oil and gas companies and local governments will also set up their own offices for it, it said. Oil and gas firms should “remove hidden dangers” that can be fixed by themselves within one year. For the problems that cannot be resolved by them alone, such as change of urban pipe layout or resettlement of residents who live too close to energy pipelines, oil and gas companies should report to the local governments to coordinate, it added. China has 655 trunk oil and gas pipelines with a total length of 102,000 kilometers. Some of them have been operating for as long as 40 years, making them vulnerable to corrosion. The explosion last November at the Dongying-Huangdao II pipeline owned by Sinopec was attributed by the government to pipeline corrosion, irregular work practices and a tangled network of underground pipes. The case highlights the risks involved as both energy pipeline networks and China’s cities expand rapidly. Urban development has engulfed many existing pipelines, providing an opportunity for thieves but also leaving lines dangerously close to residents, industry and commerce.

ExxonMobil Announces New Projects to Expand Specialty Hydrocarbon Fluid Production ExxonMobil Chemical is increasing production of its high performance hydrocarbon fluids by about 10 percent through expansion projects at its Singapore and Antwerp facilities. The additional capacity, designed to meet rapidly expanding global demand for hydrocarbon fluids and extend the company’s worldwide supply capability, will begin producing by mid-2015 and be complete in 2016. “The investments in new capacity at our Singapore and Antwerp facilities demonstrate ExxonMobil’s commitment to meet evolving customer needs,” said Elissa Sterry, vice president of intermediates products, ExxonMobil Chemical Company. “Our fluids are tailored to meet specific enduse requirements, providing customers with a competitive advantage. As a fully integrated company, access to our own feedstocks reinforces supply security for our customers.” ExxonMobil Chemical is the leading producer of hydrocarbon fluids specifically formulated for resource extraction, industrial processing and a wide range of consumer applications. The company’s portfolio of fluids includes ultra-low aromatic grades that deliver the highest performance standards while complying with stringent environmental and regulatory requirements. “ExxonMobil’s specialty products, such as our Escaid™ fluids, improve performance and safety in extended-reach drilling and solvent extraction processes for mining applications,” said Declan Dixon, ExxonMobil fluids marketing manager. “Our Exxsol™ fluids, with extremely-low aromatic content and low odor, are effectively and efficiently replacing traditional industrial and consumer solvents.” The expansion projects, which upgrade refining streams into specialty chemical products, are in progress and build on other recently announced large investment projects in the company’s Singapore and Antwerp facilities. Singapore is ExxonMobil’s largest integrated refining and chemical manufacturing site. The company has expanded production in Singapore to meet expected demand across the Asia Pacific region. ExxonMobil’s capacity expansion in Antwerp is among other investments totaling more than $2 billion over the last decade at the facility. The expanded hydrocarbon fluids unit will further strengthen ExxonMobil’s integrated downstream and chemical portfolio in northwest Europe to better compete in the global industry environment. Hydrocarbon fluids, including specialty brands and unique products tailored for specific applications, are available in a variety of distillation ranges and evaporation rates. They are well suited as solvents, dispersants and carriers for many applications. The ExxonMobil Chemical portfolio of high-value hydrocarbon fluids include the Exxsol™ D, Escaid™, Isopar™, Somentor™ and Solvesso™ brands.

MIDSTREAM & PIPELINES

Containers of All Shapes and Sizes For Many Different Applications KOVAR a.s. is a main European producer of technological containers and we are honoured to continue to participate in the development of steel containers, frames and various other steel constructions. All our containers are tailored to your wishes and we always check all the details, because we believe that your projects are worthy of it. Set of technological containers

In Business since 1992, we have extensive experience and a sufficient premises to be a strong partner for you. Type

Size

Details

Welding halls

3 halls, with cranes up to 20 t

2900 m2

Assembly halls

2 large halls

3200 m2

Blasting cabin

Special box

17,0 x 7,0 x 6,0 m

Painting cabins

3 rooms with modern technology

Material preparation

Up to 18 x 7 m

Protected area all the year

1350 m2

a s

Design department is always here We like to meet all requirements from the customer. That is why we have many experienced engineers who are constantly educating themselves and we automatically offer their services to all customers, even if they begin with your work from a hand sketch or a drawings. Our drawings can be multilingual and in the latest version of 2D AutoCad, Mechanical or 3D Inventor from Autodesk. Certification The entire production process is certified according EN ISO 9001, EN ISO 14001, OHSAS 18001 and EN 1090. Our welders are approved and the supervisors are certified as “European welding technologists”. The Company and employees are certified according EN 2871 (welders certificates), EN 473 / EN ISO 9712 (qualification and certification of NDT personnel). We perform destructive tests in our factory as well. The reason is simple: we want to guarantee the highest quality of our products.

The whole production process and compliance is in accordance with strict technological procedures which are supervised by recognized certification authorities such as Lloyd´s and DNV-GL. In particular, container documentation yields a material list that ensures traceability of all used materials, records from ultrasonic, magnetic and visual testing, measuring records, prototype and loading tests records, painting protocols and final construction certificate issued by the certification authority. This whole administrative processing is carried out by KOVAR a.s. Technological containers is our specialty Our special containers are produced according to your individual wishes. You give the idea, we make it happen. We share progress of the project with you. First we start with main structure, later we add other design features and equipment that you need. Finally you decide the painting procedure to be followed and project is finished. Our special containers can be tailored to provide protection for various machines as energy packs, switch boxes, batteries, heating boiler with fuel tanks etc. CSC containers ready for your project For the ISO containers of dimensional variations 20´, 40´ or 45´ we are able to secure CSC Certification in compliance with the ISO 668 and ISO 1496 standard. This certification allows a user to stack containers on a ship and save money on your sea transport.

Welder Special offshore containers: high quality art Our offshore containers are designed and manufactured to suit customer requirements. These advanced solutions are made in accordance with EN 12079; DNV 2.7-1 incl. DNV 2.7-2 or according to NORSOK M-101. We are able to provide gastight containers or equip them with fire-protective walls according to SOLAS (up to A60 acc. to IMO 2010 / FTP Code).

Conversions and other structures We know the rules on how to keep CSC approval by conversion. We have made many adaptations of old containers to suit new requirements and have saved costs for new production. We have rich experience with the DNV and Lloyd certification process. Ask yourself, is it possible that you can also use this method and remake an old container for new challenges and/or conditions? “Why not modify an old-one to a new-one?” Offshore containers

Wide range of options The final design of your container is determined by you, our customer. You can decide about various openings, doors or set the container load. We will prepare container drawings and turn it into reality. Floor: the container floor can be adapted in various ways to carry your equipment. Reinforcement for heavy machinery or rails for motors and transformers are the most common. Various other floor designs can be made including double floor. Electrical installation: it will be mounted and wired by our highly educated staff according various standards (VDE, CH, UK, UL, IEC etc.). Your container can be equipped with light fixtures, switches, sockets, ventilation and air-conditioning units and others. We can propose our wiring diagrams or use one you have provided. Various openings and accessories: apertures and outlets in walls can be positioned specifically to interconnect your equipment. Your machinery will probably need air openings with shutters, exact penetrations for control cables, pressure flanges, mounting brackets and others. The operating staff have easy access to machinery via various types of doors and hatches. Complementary structures: we also produce a variety of metal constructions and parts that may be necessary for container operations on site. These structures are extremely adaptable for many on-site situations and can be delivered either with an galvanized or painted surface. Ventilation and air-conditioning: a lot of containers need to be mechanically ventilated or air-conditioned. It is due to the technology of our customers. We are able to help you with design using wide-range of latest technologies available on market. We also offer you solution in A/C for explosive atmospheres (ATEX). Acoustics: we always look for the best solution for you. According to your project we help you to keep unpleasant noises away from our lives. We have experience with noisesilencers, acoustic walls, and we use special anti-vibration treatments. We pay attention to detail, because we know it affects the final result. Fire-protective walls and floors: we use certified materials from recognized producers in order to be sure that it will work while saving lives and equipment. We are regularly trained to bring the latest knowledge into practice. Our containers can be equipped with the passive protection up to 120 min. according to EN 13501-2 and with an active fire-extinguishing system. It would be pleasure for us to help realize your potential. KOVAR a.s. Feel free to contact our sales department with your inquiries and questions: +420 571 425 529, +420 571 425 560 E-mail: mail@kovar.eu Web: www.kovar.eu

Nautronix Commissions Largest NASDive Digital Diver Communications System

Leading provider of through water communication and positioning technology to the offshore industry, Nautronix, has commissioned the largest NASDive digital diver communications system for GDA, who was working on an upgrade of the communication system on-board Submarine Rescue Vessel, the MV Belos for the Swedish Navy. The vessel provides support for the Swedish Navy, and is fitted with hyperbaric chambers to facilitate rescue of submariners in the event of an incident. It was recently on an exercise with the NATO Submarine Rescue system. Following that exercise, the chamber system upgrade took place, and included a full upgrade of the chamber communications system to NASDive. This involved communications to 8 individual locations in each of 4 chambers, 2 further locations in each of 5 locks and transfer chambers plus an additional 9 external communications locations, making an impressive total of 51 individual locations. NASDive is unique in digitising all speech at source, as a result of which the many problems associated with signal losses in cabling and connectors are eliminated, resulting in clear communications at all times, and along with improved unscramble algorithms and helium speech unscrambling, which are available for each communications location. System cabling is also simplified by the use of CAT5 cabling to each location, or if unavailable VDSL on screen twisted pairs would be used, both of which allow standard telecoms hardware to be utilised topside. Ethernet hubs are used to marshal the signals, and control of the system is provided via a touch screen Display and Control Unit (DCU). The dive supervisor has full control over all communication locations, and can manage the system by configuring any location into one or a number of groups, each of which the supervisor can select whether they are talking and/or listening to. Wireless supervisor headsets free up the supervisors movements to facilitate the other tasks they are responsible for, while each communication location has local control over microphone and headset volumes, and sideband levels, thus minimising the supervisors ‘housekeeping’ activities. The system was delivered 18 weeks from order following a full client witnessed FAT at Nautronix premises, and installed by the client, with final commissioning by 2 Nautronix engineers over a 4 day period 2 weeks later. The Belos installation has shown the power and flexibility of NASDive to facilitate high quality communications with a large number of locations, and be easily retrofitted to existing chamber systems. Mark Patterson, CEO for Nautronix, says “We are delighted to have supplied NASDive to GDA for the Swedish Navy and it is a significant order for Nautronix. We have recently been focusing on the development of NASDive and invested £1 million to refresh our diver communications product line which shows our commitment to the product and for the Swedish Navy to be using the system on one of their vessels is a testament to the advantages it offers to divers.”

Bulk Carriers to Adopt Wärtsilä Dual-Fuel Engine Technology The increasing use of LNG as a marine fuel is further emphasised with the latest order for Wärtsilä’s dual-fuel engine technology. A new cement carrier being built at the Scheepswerf Ferus Smit yard in the Netherlands will feature a 6-cylinder Wärtsilä 34DF main engine, making it the first bulk carrier to adopt Wärtsilä’s multi fuel capability. The ship has been ordered by JT Cement, a joint venture between Erik Thun AB of Sweden and KG Jebsen Cement of Norway. In addition to the main engine, Wärtsilä will also supply an enclosed Gas Valve Unit (GVU) for easier installation and additional engine room safety. The order with Wärtsilä was placed in August. By opting for Wärtsilä’s proven dual-fuel (DF) technology, the vessel will be able to operate on liquefied natural gas (LNG) and a choice of other fuels, including marine diesel fuel, bio fuel and heavy fuel oil. In gas mode, the engine fulfils the IMO’s Tier III requirements without need of any after treatment systems. This is especially important since the ship will operate in Northern European waters, meaning that it will spend time in Sulphur Emission Control Areas (SECA). “The arguments in favour of gas fuel are so strong that it is no surprise that more and more vessel types are adopting its use. LNG is no longer a ‘niche’ fuel for a few specific types of ship; nowadays virtually all merchant vessels can take advantage of the environmental and cost saving benefits that LNG fuel offers. Wärtsilä is proud to be a technology leader in making this possible,” says Lars Anderson, Vice President, 4-Stroke Sales, Wärtsilä Ship Power. “Wärtsilä has a well established and proven track record in dual-fuel engine technology. The selected Wärtsilä 34DF engine is a proven and flexible engine, which should ensure lower emissions and competitive energy and operation cost,” says Anders Källsson, Managing Director, Erik Thun AB. Wärtsilä has long standing relationships with both the shipyard and Erik Thun AB, having supplied a number of engines to these customers in the past. The current vessel is scheduled for delivery before the end of 2015. There is a possibility that a second cement carrier will be built as part of this particular series. The Wärtsilä 34DF engine The Wärtsilä 34DF engine is available in 6, 8, 9, 12 and 16 cylinder configurations. It can be operated on natural gas (LNG), MDF, Bio Fuel and HFO. The switch from gas to diesel can be made instantly and without loss of power. The engine has no operating restrictions and features 0 to 100% MCR (maximum continuous rating) in gas mode. The Wärtsilä 34DF engine has the lowest fuel and lube oil consumption in its class, in both gas and diesel modes.

MIDSTREAM & PIPELINES

Gazprom and Sovcomflot Expand Cooperation in LNG Transportation Gazprom and Sovcomflot named the new state-of-the-art 170,000m³ liquefied natural gas carrier (LNGC) Pskov, after one of the oldest Russian cities. The ship will be chartered to Gazprom Global LNG (GGLNG) under a long-term contract. The LNGC Pskov is the second vessel in a series of high-specification, ice class Atlanticmax LNG carriers that have been specially designed in accordance with Gazprom’s requirements, and will support Gazprom’s global commercial operations in the gas markets. The first LNGC, Velikiy Novgorod, was delivered and entered service in January of this year. The naming ceremony took place at the STX shipyard, South Korea. The LNG carriers Velikiy Novgorod and Pskov are an integral part of the cooperation between Gazprom and Sovcomflot, aimed at development of new ‘Gaz Ice’ type LNGCs for harsh environment conditions, with improved technical characteristics to meet Gazprom’s requirements. The Gaz Ice project is the result of joint cooperation between GGLNG, Sovcomflot, the Russian Maritime Register of Shipping and Russian shipbuilders. Special provisions have been made for progressive localisation of construction work for the LNGC’s at Russian shipyards. LNGCs of this type are among the most advanced vessels of their class. Their cutting-edge design (including trifuel diesel-electric propulsion systems) has been specially adapted for harsh environment operations (Ice2 according to the Russian Maritime Register of Shipping, with special hardware for operations in low temperature conditions). The design of the gas carriers complies with the latest requirements regarding environmental standards, energy efficiency, crew working and leisure conditions, as well as onboard safety. The type of cargo system (reinforced membrane structure) is suited to operations in challenging climatic conditions. This has been proven through trials carried out in collaboration with experts from the Russian Maritime Register of Shipping and the Krylov State Research Centre. The LNGC Pskov is capable of transporting gas on a year-round basis from practically all existing LNG terminals in the world, including Russia’s first LNG terminal, Sakhalin-2, and the future Vladivostok LNG terminal. Sovcomflot has always assigned a high priority to the training and education of Russia’s next generation of seafarers. Director General of Sovcomflot, Sergey Frank and Chairman of the Management Committee of Gazprom, Alexey Miller In this respect, the Group has developed strong links with Russia’s leading maritime universities and training institutions. SCF Group invited a group of cadets from the Admiral Nevelskoy State Maritime University (Vladivostok) to attend the Pskov’s naming ceremony in Busan. On this occasion the training tall ship Nadezhda, a winner of the Black Sea Tall Ships Regatta-2014, sponsored by STI and Sovcomflot, made a special call at the port of Busan on her way home. This allowed cadets to attend the naming ceremony, have a tour of the new state-of-the-art LNGC and hold a meeting with SCF management and the ship’s master. As an equal opportunity employer, SCF welcomes the fact that a significant proportion of cadets participating in the ceremony were young women, who in the future could be employed on SCF vessels. The new LNGC Pskov also has a female officer amongst her crew – the 4th officer Lyana Mitrofanova. She is a 23 year old who was born in the city of Pskov and recently graduated from the Admiral Makarov Maritime University (St. Petersburg), the former school of the legendary Anna Schetinina, the world’s first woman to serve as a captain of an ocean-going vessel. The naming ceremony was attended by: the Deputy Chairman of the Management Committee of OAO Gazprom Alexander Medvedev; Sovcomflot’s COO Evgeniy Ambrosov; the Ambassador of the Russian Federation in the Republic of Korea Konstantin Vnukov; the Rector of the Admiral Nevelskoy State Maritime University (Vladivostok), Sergey Ogay; the Captain of LNGC Pskov, Igor Panasenko, and the vessel’s crew as well as other guests. Commenting on the announcement Evgeniy Ambrosov, Chief Operating Officer of OAO Sovcomflot, said: “The growth of SCF Group’s LNG tanker fleet, with the addition of the modern, high ice class vessel Pskov, is a logical development of SCF Group’s Strategy, which envisages significant growth of the Group’s gas transportation business, in line with the new industrial energy projects in harsh environments.” ”We are very grateful to our partners at Gazprom for the trust they have placed in us and in return are pleased to be able to offer them our first-class LNG transportation services, guaranteeing reliable, efficient and environmentally safe shipping. We are confident that this ship will allow Gazprom to strengthen its position in the global LNG production and supply markets. “The LNGC Pskov is named after a historic city located in the Western region of Russia, counting over a thousand years of history. The city was renowned for its significant merchant ties, serving as a gateway to the Baltic region and beyond – linking Northern Europe with the southern part of the continent and Asia.” Nikolai Kolesnikov, Chief Financial Officer of Sovcomflot, noted: “The financing of the construction of LNGCs Velikiy Novgorod and Pskov was supported by a consortium of leading international banks from Europe and Asia – ING Bank N.V. (Netherlands), KfW IPEX-Bank GmbH (Germany) and Sumitomo Mitsui Banking Corporation (Japan). In 2013, the financing transaction was recognized by “Marine Money” shipping magazine as “The Deal of the Year” in the project finance category. Recently, the transaction has also been nominated for the “Deal of the Year” award by Lloyd’s List reflecting its robust structure and the credit quality of the deal and its participants. The long-term time-charter of Pskov by Gazprom will add to SCF Group’s portfolio of fixed-term LNG business and increase further its future contracted revenues.”

MIDSTREAM & PIPELINES

Protecting Pipelines and Subsea Cables A world leader in subsea pipeline protection, Pipeshield is a well known and highly reputable brand in the offshore oil and gas arena and a leading source of knowledge on cable protection, scour prevention and protection within renewables.

rotecting cables, one faces the same issues as when protecting pipelines but they also encounter some unique challenges, especially where the cables are laid adjacent to the mono-piles of wind turbines and where nearby seabed velocities bring scour. Ensuring stability of the cables is essential. Concrete mattresses provide scour prevention and cable stabilisation and protection. The flexible nature of the block form ensures that the cables are conformed to the seabed contour. In the event of any localised scouring around the edge of the mattress, blocks will settle into the hole to prevent undercutting. To enhance scour protection a frond system can be fitted to the mattresses prior to deployment and then activated postinstallation. In the right conditions, the fronds will attract up to 1m of sediment over and around the mattress, providing enhanced

stability and improved protection.

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In the right conditions, the fronds will attract up to 1m of sediment over and around the mattress, providing enhanced stability and improved protection.

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Since Pipeshield was granted a patent for its N2 high performance mattress system, the company continues to innovate with three further patent applications, submitted for speed-loader systems, Rock mattress systems and ROV docking devices for the offshore mattresses installation frame. Pipeshield specialises in providing Mattresses in production

innovative solutions for underwater pipeline and cable protection. A further example of that can be seen in a purpose built multiple mattress handling frame. Pipeshield having designed the frame to install the complete mattress protection layout for Wind Farm monopole foundations in a single lift. Pipeshield is approved to ISO 9001:2008, 14001:2004, ISO 18001, is a supplier member to FPAL and has achieved the VERIFY status for its quality systems. Headquartered in Lowestoft, the company maintains manufacturing bases in England and Scotland and has established a permanent manufacturing arrangement in South East Asia and production experience in the Middle East, Indonesia, Canada and South Africa. Pipeshield has been working with some of the biggest companies in this arena to develop bespoke solutions to one of the most prolific problems renewable energy has to resolve: subsea. Multi mattress lift for single deployment around a mono-pile

Transporting extra wide mattresses Pipeshield has provided mattresses on the Lynn Inner Dowsing, Gwynt Y Mor, Scroby Sands and Egmond Windpark projects.

Case Study: Lynn Inner Dowsing This project required stabilisation and protection of the inter turbine cabling. To optimise the mattress requirement, calculations were performed, optimising both the number and size of the mattresses to fit in with the installation logistics. Deck space is

always at a premium and therefore it was important to keep the total volume of mattresses to a minimum. Using a high-density concrete, the mattress thickness was kept to a minimum, whilst ensuring mattress stability .The installation used in-house designed frames that can be operated either by a diver, ROV or by remotely activating the hydraulic operation. In this case, the installer used an ROV to position and release the mattresses over the cable.

Installation frame for single mattress deployment

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The flexible nature of the block form ensures that the cables are conformed to the seabed contour. In the event of any localised scouring around the edge of the mattress, blocks will settle into the hole to prevent undercutting.

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Pipeshield International Ltd +44 (0)1502 560900 info@pipeshield.com www.pipeshield.com

MIDSTREAM & PIPELINES

Preventing Premature Failures and Extending Component Life Unexpected failure of equipment is a problem in any major industry, often resulting in costly delays and downtime. Surface finishing techniques are proven to extend the life of components and ensure optimum operating performance and should be considered, especially where components are exposed to harsh environments and challenging operating conditions.

hether specified as part of the manufacturing process or included as part of a repair and maintenance programme, surface treatments are widely recognised to solve metal and corrosion fatigue, stress corrosion cracking, fretting, spalling and wear problems which are all typical failure mechanisms for turbines, pumps, compressors, valves and welded structures and assemblies.

successful when applied to welded structures such as the change of section and areas of high stress intensity. Controlled Shot Peening can also be used to correct distortion in components which has occurred during the manufacturing process and reinstate any loss of beneficial compressive stress.

rolling of metals in contact occurs, the C.A.S.E. super finishing technique will reduce operating temperatures, noise and friction and also improve resistance to macro and micro pitting, but still retain critical lubrication. It is a two part process where the component is first shot peened and then followed by an isotropic

Surface treatments have been used through the ages to strengthen metals. During the 11th Century the sword makers of Toledo used a cold hammering technique to produce highly prized lightweight swords, which were extremely strong and held their sharp edge. The development of surface treatments has been continuous in adapting to meet the needs of modern manufacturing and materials. The growth of robotic engineering has allowed the processes to be strictly controlled, repeatable and highly accurate and portable equipment is also available to perform onsite work where it is impractical to move the components to a dedicated facility. The main categories of surface treatments widely recognised in the aerospace, automotive, oil & gas, energy and petrochemical and medical markets include: Controlled Shot Peening, Laser Shock Peening, C.A.S.E. Super Finishing and Engineered Coating applications, including Thermal Spray, Dry Film Lubricants, Diffusion and Parylene coatings. Below is a brief outline of these main processes: Controlled Shot Peening Residual tensile stress typically introduced during the manufacturing process and also unexpected service conditions are a major cause of premature failure in components. Controlled Shot Peening can convert this harmful stress into beneficial residual compressive stress by modifying the characteristics of the material at the surface and sub-surface. This technique is also

Laser Shock Peening Laser peening has the ability to surgically place residual compressive stress via a laser beam pulse into key areas of a component to retard crack initiation and growth. For most applications the Controlled Shot Peening process will give excellent results but in some circumstances Laser Shock Peening is the preferred method where a far deeper layer of beneficial compressive stress can be achieved. The process will give resistance to low cycle, high stress situations (LCF) and high cycle, low stress situations (HCF) in a deteriorating surface environment. Examples of applications include electrical power gas and steam turbines, jet engine fan blades and automotive engines. C.A.S.E. Super finishing In circumstances where both sliding and

Shot Peening Influence on Applied Stress finishing technique where the component is gently rolled and rotated through oxalic acids and non-abrasive finishing stones to gradually hone the peak surface areas, but retain the valleys for optimum lubrication. Engineered Coatings The application of the correct engineered coating system will protect components against corrosion, improve part wear life and performance and also reduce maintenance costs. There are a wide range of coatings available depending on the operating conditions and substrate material which when combined with pre-treatments and primers will give excellent protection from adverse

Parylene Coating This is an ultra-thin, biocompatible coating which is pinhole-free and completely conformal, whatever the size and shape of the component. It is widely used in the medical market, but also used to shield electronic systems from electromagnetic interference and corrodants, corrosive chemicals and solvents. Diffusion Coatings

Laser Shock Peening Process corrosion, environmental and chemical attack as well as preventing friction, aid lubrication and reduce noise. The following is a brief outline of the typical coatings used in the industry: Thermal Coatings Thermal Spray coatings provide abrasion resistance, high temperature oxidation/ corrosion protection and solid particle erosion control. It is robotic controlled which allows for a uniform coating of multifaceted and complex shapes. In some cases worn parts can be brought back to original specification.

Dry Film Lubricants Everlube速 coatings and products are widely used to provide both corrosion protection and dry film lubrication. The range includes Everslik 1201/1301 which is a core coating system consisting of an extremely tough and durable coating primer with salt spray resistance of 2500hrs, followed by the application of a high loading MoS2 based dry film lubricant. This coating system is typically used for pumps, valves, connectors, actuator systems and shafts, fasteners and jack screws.

These coatings are typically used for substrate materials such as cobalt and nickel based super alloys and steels used for gas turbine engine components, pump impellers and gate valves. Diffusion coatings offer a high level of resistance to corrosion, erosion and oxidation. The components are coated with a non-corrosive material and usually applied in a controlled chamber at high temperature. Material Testing Services Material testing, failure analysis, chemical analysis and weld testing are essential to ensure design and manufacturing integrity to give optimum performance.

Typical application techniques include HVOF (high velocity oxy fuel) combining hydrocarbon fuel and oxygen which is ignited within a combustion system resulting in a high pressure flame which propels semi-molton material onto the surface. This coating is built up in layers to form a secure bond as each particle cools which can withstand extreme mechanical loads and severe wear conditions. The Plasma spray technique uses a controlled gas stream which is electrically ionised to create a high temperature plasma plume (up to 20,000 degrees Kelvin). Thermal Spray Robotic Application Surface treatment technology continues to evolve today, as manufacturers demand greater strength and performance from lighter and ever more complex components and structures. Our mission is to make sure that we continue to meet these exciting challenges today but also look at what requirements and challenges might present for our customers and the industry in the future.

Curtiss-Wright Surface Technologies Global Facilities and Onsite Work For more information and contact details: www.cwst.co.uk

C.A.S.E. Process Surface Topography

PROCESSING

Total Relies on High Performance Computing with SGI and SUSE As new oil and gas reserves become more elusive, companies like Total rely increasingly on high performance computing (HPC) to find opportunities in an ocean of seismic data. With SUSE Linux Enterprise Server as the operating system for its new SGI supercomputer, Total now has an optimal combination of performance, price and efficiency. The solution – called “Pangea” – delivers 10 times the computing capacity of the system it replaced, helping Total identify and exploit new reserves more effectively. “We clearly saw that the price-performance of SUSE Linux Enterprise Server on the SGI platform was better than the competing OS options,” said Diego Klahr, HPC engineer at Total E&P. “And from our point of view, SGI plus SUSE Linux Enterprise Server was a complete, integrated solution.” Operating in 130 countries, Total is the fifth-largest publicly traded integrated oil and gas company. In addition to downstream activities in refining, marketing, trading and shipping of crude oil and petroleum products, Total has upstream exploration and production capabilities in more than 50 countries. The challenge for Total Exploration & Production (Total E&P) is to continually improve its ability to locate new reserves and cost effectively bring them into production. This process depends heavily on the computer-aided analysis and visualization of huge sets of seismic data, which is gathered by generating waves of vibration and measuring how hidden geological structures reflect them. To discover and exploit smaller and less accessible reserves, Total E&P set out to improve the resolution of its visualizations, which meant significantly increasing the computing power at its disposal. Total E&P selected SGI to build the new Pangea supercomputer based on the SGI ICE X High Performance Computing platform, including innovative M-Cell water cooling. “Pangea is an extremely powerful solution for running numerical models in support of three-dimensional visualizations of subterranean geological formations,” Klahr said. “Using the system, we can run 10 times the number of simulations we run with our previous supercomputer, helping us to identify potential deposits and determine the best extraction methods more easily.” The combination of SUSE Linux Enterprise Server with SGI hardware, cluster management software and deployment services has given Total E&P a supercomputer that is both powerful and highly efficient. The SUSE Linux Enterprise Server operating system provides a fast and stable platform for Total E&P’s specialized applications, and its small footprint helps to maximize performance by minimizing overhead on the Xeon processors.

LyondellBasell Introduces New Hostalen RESIST Grade for Gas Distribution Piping Systems LyondellBasell announced the addition of Hostalen CRP 100 RESIST CR Orange to its comprehensive portfolio of high density polyethylene (HDPE) resins for pipe applications. This new RESIST grade is used by customers in non-conventional pipe installation methods, such as no-dig or sand bed free installation for gas distribution piping systems. “This new grade fulfills the material requirements of the Publicly Available Specification (PAS) 1075:2009-04, which defines properties and requirements for PE piping for alternative installation methods“, said Detlef Schramm, polyethylene pipe marketing manager for LyondellBasell. “The quality control and safety levels described by this PAS define a useful service life of at least 100 years for this type of material, including higher resistance properties“. Outstanding stress crack resistance Hostalen CRP 100 RESIST CR Orange is classified as PE 100-RC and provides outstanding long term hydrostatic strength, which is confirmed by the Exova technical laboratory, the standard method ISO 9080:2003 and the Hessel testing laboratory. This resin has superior resistance to slow crack growth, achieving more than 9,500 hours without failure in the Notched Pipe Pressure Test (NPT) and over 8,760 hours in the Full Notch Creep Test (FNCT). In addition, it provides high safety for installations without sand embedding, with direct back filling or reuse of excavated soil, by ploughing-in or milling, and for no dig installations (such as horizontal drilling or burst lining). Hostalen CRP 100 RESIST CR Orange offers good processing capability with high melt viscosity for extrusion, injection and compression molding. Extensive RESIST portfolio The comprehensive Hostalen RESIST family of grades is produced using LyondellBasell’s Advanced Cascade Process (ACP) technology. In addition to Hostalen CRP 100 RESIST CR Orange, these HDPE resins are also selected by customers for use in alternative installation methods for pressure pipes, where Hostalen CRP 100 RESIST CR Black is preferred, and for drinking water pipes, where Hostalen CRP 100 RESIST CR W Blue is used.

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SPECIAL: LUBRICANTS

Improving Safety and Productivity: The Role of Lubricants in Achieving Operational Excellence A special report with ExxonMobil. For the global energy exploration sector, safety remains absolutely paramount. However, oil and gas operators are also faced with increasingly challenging energy cost rises and environmental care goals. For a complex industry which is split across remote geographical locations across the globe, achieving the balance of these conflicting imperatives is an ambitious challenge. Could a solution lie in lubricants? Advanced lubricants and greases help mitigate potential injury risks and simultaneously increase overall productivity for owners and operators in the oil and gas sector. This article looks at how.

Safety First Safety is the number one priority for operators in the oil and gas industry, with maintenance procedures carried out during scheduled and unscheduled downtime often placing engineers in hazardous situations. One equipment failure can bring an entire operation to a halt; and with operators often working in quite isolated environments, it is imperative that they are able to do their jobs as safely and efficiently as possible. By taking proactive measures to extend equipment life and improve operating standards, operators can decrease the amount of exposure their engineers have to hazardous maintenance procedures and also increase overall productivity. To ensure efficient operations and help equipment continue working long-term, oil and gas operators rely on a number of lubricants. Advancements in lubricant technology, especially in the fully-synthetic product market, have seen significant breakthroughs in extending equipment life compared to conventional mineral oils, lengthening oil drain intervals and improving the energy efficiency of equipment. Synthetic lubricants are designed to work at higher operating temperatures than mineral oils, helping to extend equipment life. For example, in addition to these benefits, Mobil SHC™ fully synthetic oils also create potential energy savings while helping to increase worker safety by minimising potentially hazardous maintenance. The low traction and high viscosity index in the Mobil SHC 600 series significantly reduces power consumption and energy costs compared with conventional mineral oils and can contribute to reduced energy consumption up to 3.6 percent.* Mobil SHC Pegasus series can increase fuel efficiency up to 1.5 percent** more than conventional oils. Productivity… and beyond While safety is paramount, productivity remains important. Oil and gas operators care about the financial output and continue to look for ways to increase production. In addition to the benefits outlined above, advanced

Photos courtesy of ExxonMobil lubricants can also contribute to enhancing overall oil rig productivity. Reduced number of oil changes as a result of extended oil drain intervals, fewer oil purchases, and less labour and waste help lower operating costs and maximise engine availability, which can bring significant savings and make business more profitable. For example, an oil and gas company operating in Egypt needed its heavy duty diesel generators to operate continuously to supply electricity for submersed/submersible pumps in oil wells. Following a switch from a mineral oil to a synthetic multi-grade diesel engine oil, Mobil Delvac 1™ SHC, oil drain intervals extended by more than three times, thus reducing downtime for oil change and improving safety. Thanks to this, and through minimising spare parts consumption, the company has saved an average of US$165,640 per diesel generator, per year. Through the introduction of Mobil Polyrex™ EM high performance electric motor grease, an oil refinery in Turkey has significantly reduced the amount of maintenance required and made significant savings. The conventional grease previously used to lubricate the electric motor and fan bearings in the refinery’s processing

units was unable to provide sufficient protection, resulting in frequent bearing failures and unscheduled downtime. Following the introduction of Mobil Polyrex EM, a highperformance grease that provides lubrication even at operating temperatures as high as 170°C (338°F), the company has seen a decline of 43 percent in bearing replacements for its electric motors and fans, significantly reducing hazardous maintenance work and resulting in an average cost saving of US$252,000 per year. Conclusion Safety, environmental care and productivity are intrinsically linked. Mobil products and services are designed to help minimise downtime by providing long drain intervals and improving equipment reliability. They support oil and gas industry operators in increasing the safety of their staff; some of the lubricants’ properties also improve energy efficiency , which in turn helps to reduce some environmental impacts and to deliver operational excellence beyond productivity. For more information about Mobil-branded lubricants and services, please contact the ExxonMobil Lubricants Technical Help Desk on TechDeskEurope@exxonmobil.com

Notes * Energy efficiency relates solely to the fluid performance when compared with conventional reference oils of the same viscosity grade in gear applications. The technology used allows up to 3.6% efficiency compared with the reference when tested in a worm gearbox under controlled conditions. Efficiency improvements will vary based on operating conditions and applications.

Wheel bearing

** The fuel efficiency of Mobil SHC Pegasus relates solely to the fluid performance when compared to ExxonMobil’s standard SAE 40 natural gas engine oils. The technology used in Mobil SHC Pegasus demonstrated up to a 1.5% increase in fuel efficiency compared to Mobil Pegasus 1005 and 805 series when tested in standard natural gas engine applications under controlled conditions. Efficiency improvements will vary based on operating conditions. The energy efficiency claim for this product is based on test results on the use of the fluid conducted in accordance with all applicable industry standards and protocols.

UPCOMING EVENTS 27 Oct - 28 Oct

5th Annual Shale Gas Environmental Summit

Holiday Inn Regents Park, London, UK Organiser: SMi Group Contact: agibbons@smi-online.co.uk www.smi-online.co.uk 28 Oct – 29 Oct

Offshore Energy 2014

Amsterdam RAI, The Netherlands Organiser: NAVINGO BV Contact: ao@navingo.com www.offshore-energy.biz Oct 28 – Oct 30

European Autumn Gas Conference

Grange St Paul’s Hotel, London, UK Organiser: dmg :: events (UK) Ltd Contact: laurenceallen@dmgevents.com www.theeagc.com 19 Nov – 21 Nov

Azerbaijan Oil & Gas Summit 2014 Four Seasons Hotel, Baku, Azerbaijan Organiser: Oliver Kinross Ltd Contact: +44 (0) 20 7127 4501 www.azerbaijansummit.com 24 Nov - 25 Nov

4th Annual Oil and Gas Cyber Security

Marriott Hotel, Regents Park, London, UK Organiser: SMi Group Contact: agibbons@smi-online.co.uk www.smi-online.co.uk 02 Dec – 05 Dec; 10:30am to 6pm

OSEA 2014

10 Bayfront Ave, Marina Bay Sands, Singapore Organiser: Singapore Exhibition Services Pte Ltd Contact: jaime@sesallworld.com www.osea-asia.com 20 Jan – 22 Jan

Offshore West Africa 2015

The Landmark Events Centre, Water Corporation Road, Victoria Island Annex, Lekki Peninsula, Lagos, Nigeria Organiser: PennWell Conferences & Exhibitions Contact: Headquarters@PennWell.com www.offshorewestafrica.com

26 Jan – 28 Jan

Offshore Middle East 2015

Qatar National Convention Centre, Education City, Doha, Qatar Organiser: PennWell Conferences & Exhibitions Contact: Headquarters@PennWell.com www.offshoremiddleeast.com 27 Jan – 29 Jan

Marcellus-Utica Midstream Conference & Exhibition 2015

David L Lawrence Convention Center, 425 Sixth Avenue, Suite 1850, Pittsburgh, PA 15219, USA Organiser: Hart Energy Publishing Lllp Contact: bcraigwell@hartenergy.com www.marcellusmidstream.com 28 Jan – 31 Jan

Chemtech World Expo 2015

Bombay Exhibition Centre - NSE Exhibition Complex, Highway, Goreagon (East), Mumbai - 400 063, India Organiser: Chemtech Foundation Contact: conferences@jasubhai.com www.chemtech-online.com/events/chemtech/ 18 Feb – 19 Feb

Mexico Shale Summit

Hilton Palacio del Rio, San Antonio, TX, USA Organiser: Industry Exchange LLC Contact: dmancera@mexicoshalesummit.com www.mexicoshalesummit.com 18 Feb – 21 Feb 03 Sept – 06 Sept

CAIRO ENERGY 2015

Cairo International Convention & Exhibition Centre, Nasr Road, Nasr City, Egypt Organiser: Pyramids Group Egypt Contact: cengiz.gumus@pyramidsfair.com www.pyramidsfair.com Mar 3 – Mar 6

OIL, GAS & POWER ASIA 2015 Karachi Expo Centre, University Road, Karachi, Pakistan Organisers: Ecommerce Gateway Pakistan Pvt. Ltd. & Ecommerce Gateway Pte. Ltd. Contact: info@ecgateway.net.pk www.ogpoasia.com

UPCOMING EVENTS 08 Mar – 11 Mar

MEOS 2015

Mar 25 – Mar 26

Oil & Gas Outlook North Sea

Bahrain International Exhibition & Convention Centre (BIECC), Building 158, Avenue 28, Sanabis, Block 410, Bahrain Organisers: Arabian Exhibition Management, Allworld Exhibitions, SPE & BECA Contact: aeminfo@batelco.com.bh www.aemallworld.com

Mercure Aberdeen Ardoe House Hotel and Spa, South Deeside Road Blairs, AB125YP Aberdeen, United Kingdom Organiser: Terrapinn Holdings Ltd Contact: enquiry.uk@terrapinn.com www.terrapinn.com

Mar 9 – Mar 12

Mar 26 – Mar 28

Myanmar Oil & Gas 2015

Traders Hotel and MCC, Yangon, Namibia Organisers: Fireworks Trade Media Pte Ltd & GiMA International Exhibition Group GmbH Contact: myamar@asiafireworks.com www.oilmyanmar.com 11 Mar – 13 Mar

Australasian Oil & Gas Expo 2015

Perth Convention Exhibition Centre, Cloisters Square, Perth Western 6850, Australia Organiser: Diversified Exhibitions Australia Contact: aog@divexhibitions.com.au www.aogexpo.com.au Mar 17 – Mar 19

STOCEXPO Europe 2015

Ahoy Rotterdam, Ahoy’-weg 10, 3084 BA Rotterdam, Netherlands Organisers: Stocexpo Ltd. & easyFairs Netherlands BV Contact: info@stocexpo.com www.stocexpo.com Mar 23 – Mar 25

Arctic Technology Conference 2015

Bella Center, Center Boulevard 5, DK-2300 Copenhagen S, Denmark Organizer: SPE (Society of Petroleum Engineers) Contact: awegener@aapg.org www.arctictechnologyconference.org

CIPE 2015

New China International Exhibition Center, No.88, Yuxiang Road, Tianzhu, Shunyi District, Beijing, China Organiser: Beijing Zhenwei Exhibition Co.,Ltd. Contact: cippe@china-zhenwei.com.cn www.cipe.com.cn/2015 Mar 26 – Mar 28

EXPEC 2015

New China International Exhibition Center, No.88, Yuxiang Road, Tianzhu, Shunyi District, Beijing, China Organiser: Beijing Zhenwei Exhibition Co.,Ltd. Contact: dl@zhenweiexpo.com www.expec.com.cn/2015 Mar 31 – Apr 02

Offshore Asia Conference & Exhibition 2015

Kuala Lumpur Convention Centre (KLCC), Kuala Lumpur City Centre, 50088 Kuala Lumpur, Malaysia Organiser: PennWell Conferences & Exhibitions Contact: Headquarters@PennWell.com www.powergenasia.com Apr 27 – Apr 29

Oil & Gas Expo East Africa 2015 KICC, Nairobi, Kenya Organiser: Expogroup Contact: jason@expogr.com www.expogr.com/kenyaoil/

Mar 25 – Mar 26

GIOGIE 2015

Sheraton Metechi Palace Hotel, 20 Telavi Street, Tbilisi, 0103, Georgia Organisers: Iteca Kavkasia, ITE Group Plc. & GiMA International Exhibition Group GmbH Contact: office@iteca.ge www.giogie.com

May 4 – May 7

Offshore Technology Conference Reliant Center – Houston, Houston, TX 77054, USA Organiser: SPE (Society of Petroleum Engineers) Contact: spedal@spe.org www.otcnet.org

For safe production in deep water, use Sandvik wire for critical wireline and welding applications

Sandvik has always strived to be at the cutting edge of materials technology by continually developing new materials, technologies and products that meet or exceed our customersâ&#x20AC;&#x2122; expectations; from increasing productivity and improving performance to reducing environmental impact. Health and safety are also integral parts of our business and are at the forefront of all activities within our operations. This is one of the main reasons why we are currently a global, world-leading company, operating in 130 countries.