Wednesday, 30 September 2015

ACE Winches support pilot engineering course for Turriff pupils - 30/09/2015

ACE Winches support pilot engineering course for Turriff pupils

Global deck machinery specialist, ACE Winches in partnership with Turriff Academy, ITCA Training and Aberdeenshire Council have launched a pilot engineering course for Turriff Academy pupils this month (September 2015).

The senior phase course aims to meet the development needs of Scotland’s Young Workforce, a framework led by Sir Ian Wood supporting organisations looking to recruit, retain and develop young people and backs ACE Winches’ wider youth development CSR strategy.

ACE Winches CEO, Alfie Cheyne said: “We are committed to supporting young people within the local community to afford them opportunities in their future career and personal goals.

“It is a pleasure to be part of this offer to Turriff Academy students which includes industry standard training allowing aspiring apprentices to obtain essential engineering and health and safety qualifications. 

“Training is a core service of our business and our ACE Winch Academy has been providing programmes for all aspects of winch and spooling operations for five years.”

The seven-month pilot session will support 16 pupils and deliver three theory units based at school using ITCA resources and two practical units delivered at ITCA in Dyce. The three theory units are Health and Safety, Working with Others and Understanding Engineering Drawing under Performing Engineering Operations SVQ level 1-5.

SQA Employability may also be an option as an introduction to Mechanical Engineering. Successful pupils would gain 47 SCQF points for Mechanical Engineering or 43 SCQF points for the Welding option.

Jane Bisset, depute rector, Turriff Academy commented: “The rural location of Turriff makes it extremely difficult for the school to pay for the transport needed to access apprenticeships and training for the engineering field.

“We have 24 S4-S6 pupils interested in an engineering course, which would not be possible without the generosity of the partners involved due to specialist staff shortages in technologies at the school.

“This initial training providing an industry standard PE01 course instead of the usual type of school-based course is a significant step forward for us and I’d like to thank everyone involved for enabling our students this invaluable opportunity.”

For pupils desiring to enter the industry after leaving school they would also require to have at least National 4 Maths and also a National 4 in either Graphic Communication, Design and Manufacture or Practical Craft.

Mr Cheyne said: “Fostering and developing people is a strongly embedded value at ACE Winches and the partnership with Turriff Academy and ITCA is an example of how we are putting this belief into action.

“This summer for the fifth consecutive year we gifted perpetual trophies for technology and science.  Pupils from Turriff Academy, Banff Academy and Buckie High School were identified for their outstanding skills and knowledge in the STEM subjects.” 

ACE Winches appoints Indonesian local representative and agent - 30/09/2015

ACE Winches appoints Indonesian local representative and agent

ACE Winches a global leader in the design, manufacture and hire of winches, marine deck machinery and the provision of associated hire personnel for the offshore oil and gas, marine and renewable energy industries has appointed a new representative in Indonesia to expand its international business. 

To enhance support to existing clients and secure new contracts in South East Asia, ACE Winches has appointed Indonesian company Abumas in Jakarta as its local representative and agent.   

Managing Director of Abumas, David Philp, stated: “Abumas is a group of companies supplying products and services to the oil and gas industry in South East Asia with a primary focus in Indonesia. We are delighted to have ACE Winches on our vendor list and have the opportunity to work with them to support the offshore sector operating out of Indonesia.”

Alfie Cheyne, ACE Winches’ CEO stated “Abumas Group was instrumental in supporting us on a recent contract to supply equipment and personnel to a major operator involved in the Jangkrik Muara Bakau Block Project.  ACE Winches supplied products and services to support its well intervention and subsea well head deployment activities.”

In addition to the equipment ACE Winches supplied multi-skilled personnel to work with and train the operator’s crew in specialist winch applications. 

A number of ACE Winches clients are currently working in South East Asia and recently the company has successfully secured and delivered £10m in equipment and products.  The company was looking at how it could provide further support from within the region as it expands its international markets. Having a partner based in Indonesia will enable the company to quickly connect with oil and gas companies to provide them with the full product range, expert advice and technical expertise to help manage their specific requirements.  

Delineation of oil and gas discovery 7220/11-1 in the Barents Sea - 30/09/2015

Delineation of oil and gas discovery 7220/11-1 in the Barents Sea

Lundin Norway AS, operator of production licence 609, has completed the drilling of appraisal wells 7220/11-3 and 7220/11-3 A on the oil and gas discovery 7220/11-1 (Alta).
The wells were drilled about four kilometres south of discovery well 7220/11-1 and approximately three kilometres northeast of appraisal wells 7220/11-2 and 7220/11-2 A.

Discovery 7220/11-1 was proven in limestones in the Gipsdalen group in October 2014. After drilling of the discovery well, the operator's resource estimate for the discovery was between 14 and 50 million Sm3 recoverable oil and between 5 and 17 billion Sm3 recoverable gas.

The purpose of the wells was to delineate discovery 7220/11-1, and additionally to investigate the extent of the reservoir and hydrocarbon columns. Well 7220/11-3 encountered a 75-metre thick gas column and the upper part of an oil column in limestones in the Gipsdalen group of good to very good reservoir quality. Due to technical challenges, the well was plugged.

A decision was made to drill a sidetrack, 7220/11-3 A, about 400 metres to the southeast. The well encountered a 74-metre hydrocarbon column, 30 metres of which was a gas column and 44 metres was an oil column in reservoir rocks of good to poor reservoir quality. The age of the reservoir rock is uncertain, but is assumed to be of Triassic and/or Permian age. The well was temporarily plugged and abandoned to have the opportunity to return to it to drill deeper and, if relevant, perform a production test.

Pressure gradients from wells 7220/11-3 and 7220/11-3 A show communication with discovery well 7220/11-1.

Extensive data acquisition and sampling have been carried out in both wells.

The results from the appraisal wells are important for the further work of mapping the east flank of the discovery. The resource estimate will be reassessed based on the new data.

These are the fourth and fifth exploration wells in production licence 609. The licence was awarded in the 21st licensing round in 2011.

Appraisal wells 7220/11-3 and 7220/11-3 A were drilled to measured depths of 1926 metres and 2105 metres, respectively, and vertical depths of 1925 and 1962 metres below sea level, respectively, and were terminated in the Gipsdalen group of Permian age. The water depth is 397 metres.

The wells were drilled by the Island Innovator drilling facility, which will now drill wildcat well 7220/6-2 in the same production licence.

Tuesday, 29 September 2015

Gazprom going on with comprehensive efforts on import substitution by Russian prototypes - 29/09/2015

Gazprom going on with comprehensive efforts on import substitution by Russian prototypes

The Gazprom Board of Directors took notice of the information about the ongoing minimization of dependence on the foreign equipment supply.

It was highlighted that the Company had been pursuing a comprehensive import substitution strategy for years. As a result, the share of home-produced equipment accounted for about 95 per cent in Gazprom Group’s procurement portfolio.

Gazprom going on with comprehensive efforts on import substitution by Russian prototypes
The Company approved a list of essential products that had to be substituted and produced domestically. Based on this list, the ways of launching competitive import substitution were studied, as well as the critical areas and reasonable timeframes for further minimization of import dependence were defined.

The import substitution objectives are achieved, for instance, by establishing technology partnerships with Russian producers of oil and gas equipment.

Thus, Gazprom has long-standing cooperation with machine building and pipe companies, aimed, inter alia, at mastering cutting-edge technologies and initiating production of domestic equipment not inferior to its foreign analogues for Gazprom’s needs. Among the Company’s partners are Cryogenmash, United Metallurgical Company, OMZ, REP Holding, Severstal, Pipe Metallurgical Company TMK and Chelyabinsk Pipe Rolling Plant.

The meeting pointed out that close interaction with Gazprom enabled Russian leading machine building and pipe companies to start the mass production of cutting-edge and unique pipes for gas trunklines, high-tech inspection, transmission and other types of home-produced equipment.

The Company is in close liaison with Russian region authorities; thus, Gazprom and 19 constituent entities are implementing roadmaps for a wider application of locally manufactured products and technologies, including the import substituting ones, at Gazprom’s facilities. After acceptance, these domestic technologies are permitted to be used by Gazprom and may be purchased via a tendering procedure.

The ‘New Technologies in Gas Industry’ Association of Equipment Manufacturers has been established and successfully coordinates activities of national enterprises. The list of imported products recommended for substitution by Russian manufacturers can be found on Gazprom’s official website.

In a while, Gazprom is going to try a new way of cooperation with potential manufacturers of import substitution products: long-term agreements will stipulate that Gazprom guarantees to buy a fixed amount of equipment to be produced, supplied and maintained by domestic manufacturers. Several pilot projects will test this new way of business relations.

Dealing with import substitution, Gazprom uses a comprehensive approach, which includes technical regulation, i.e. national and corporate standardization, compliance assessment and quality control. The Company has developed over a thousand of in-house standards, most of them are related to oil and gas equipment, and they contain even more stringent reliability and safety requirements than their national and international counterparts.

In addition, Gazprom and Russia’s Ministry of Industry and Trade signed the Import Substitution Program for industrial products needed by Gazprom, its subsidiaries and affiliates. According to the document, manufacturers may receive some state support, including subsidy assistance and favorable lending rates.

The Management Committee is tasked to annually submit a progress report on import substitution projects to the Board of Directors.

THE SECRET THAT IS CERTAS ENERGY - 29/09/2015

THE SECRET THAT IS CERTAS ENERGY

Certas Energy is one of the largest distributors of fuel and lubricants in Britain, supplying domestic, commercial, agricultural and industrial customers. 

Delivering world-class fuels and lubricants to around 1,200 independent petrol retailers, Certas Energy is the company in Britain with a national infrastructure that can efficiently cater for the largest dealer groups and smaller sites alike.

With 150 depots and strategically placed offices throughout Britain, with the England and Wales Head Office in Warrington and Scottish Head Office in Larbert, Stirlingshire, Certas Energy has grown through acquisition and organic growth, now with over 1,000 tankers on the road at any given time.

In the automotive aftermarket Certas is responsible for several recognised brands including; Shell, Castrol, Gulf and Valvoline. These market leading brands meet the requirements of every major sector, including: agricultural, automotive, commercial, manufacturing, industrial, haulage, marine and aviation.

Shell Lubricants brings world-class technological insights to its products, offering the best vehicle formulations.

Castrol is the world leading manufacturer, distributor and marketer of premium lubricating oils, greases and related services to the automotive, industrial, marine, aviation, oil exploration and production customers across the world.

Gulf Oil has been at the cutting edge of the development and distribution of fuel since oil was first discovered in Texas in 1901. Gulf’s range of premium fuel and lubricant products has continued to evolve, pushing the boundaries of innovation and excellence to lead the market in terms of performance, technology and compliance. Gulf Oil continues to excel in its long tradition of product innovation over the last hundred years, bringing technically proven, and quality products to market. Certas Energy is the only official UK distributor for Gulf oils and lubricants.

Tony Stewart, director for Scotland at Certas Energy, has worked in the oil distribution business for over 25 years and commented: “Over the last few years, Certas Energy has positioned itself as the one of the most significant businesses in its sector and gone through a series of strategic acquisitions to cement itself as the largest distributor of fuel and lubricants in Britain.

“Certas Energy is now on a tactical campaign to find distributors and stockists for its extensive product ranges across all brands and is concentrating initially on the aftermarket through the factor to workshop and the retail to consumer.”

Polarled Pipeline now in place - 29/09/2015

Polarled Pipeline now in place 

On Monday 28 September, the final pipe in the 482.4 kilometre long Polarled Pipeline was laid at the Aasta Hansteen field at a depth of 1,260 metres in the Norwegian Sea.

Polarled is the first pipeline on the Norwegian continental shelf that crosses the Arctic Circle and opens up a brand new highway for gas from the Norwegian Sea to Europe.

The pipeline, which has a diameter of 36 inches, extends from Nyhamna in Møre og Romsdal to the Aasta Hansteen field in the Norwegian Sea and was laid by the world's largest pipelaying vessel: “Solitaire” from Allseas.

Bilde
The Polarled Pipeline is now in place.
The pipelaying work commenced in March this year and the pipeline consists of more than 40,000 pipes, each of which is 12 metres in length.  Polarled is the deepest pipeline on the Norwegian continental shelf. At the Aasta Hansteen field, the pipeline reaches a depth of 1,260 metres.

It is the first time ever that a pipe that is 36 inches in diameter has been laid at such a depth.  The pipeline’s capacity will be up to 70 million standard cubic metres of gas per day.

Money saved
"We are delivering Polarled under budget. The original investment budget for the pipeline project was NOK 11.1 billion. We now expect an investment level of around NOK 7.5 billion. This is due to good planning, good market knowledge and good execution - and the fact that we could combine several large projects when we went to the market and negotiated for pipes and vessels. Based on this, we were able to achieve favourable conditions in the market with regard to capacity and price," says Torger Rød, head of projects in Statoil.

Building for the future
In the initial stage, only the gas from Aasta Hansteen will be transported through Polarled, however the 36-inch diameter pipe has space for more:

"We have therefore installed six connection points. Call them future slip roads to the new gas highway," says Håkon Ivarjord, project director for the Polarled development project.

"With this pipeline, we open up for the export of gas to Europe from a completely new area, and with the infrastructure in place it will also be more attractive to explore the area," he concludes.

“Energy supply security is essential to the EU and the individual European countries. Tying in a new Norwegian Sea area  to the gas transportation network Polarled will be an important link for further gas export, thus strengthening Norway’s position as a reliable supplier to the European gas market,” says Grete B Haaland, head of  asset management in Statoil’s  Marketing, Midstream and Processing business area.

Monday, 28 September 2015

Inside Oil & Gas Issue 9 Preview - 28/09/2015

Peterson launches new Transport Request Tool - 28/09/2015

Peterson launches new Transport Request Tool

Leading international energy logistics company Peterson has announced the launch of its Transport Request Tool (“TRT”), designed to digitally streamline the offshore transport order process and is the latest application in Peterson’s growing suite of digital applications. 

Following the successful introduction of Peterson’s eCargo, the first system to digitise quayside operations making them more transparent and efficient, the next step was to digitally streamline the offshore transport order process. With this new innovative solution, cargo items are no longer treated as cargo for a specific vessel, but as a request to be transported. The new tool removes the need for duplicate data input allowing clients to enter their transport requirements directly via TRT, removing unnecessary over processing in the supply chain allowing Peterson to focus on adding value to the customer in other ways.

Ron van der Laan, regional director, Peterson commented: “New technologies are fundamental to enable the oil and gas industry to streamline and enhance operational efficiencies both on and offshore. 

“With the increased focus on long term cost reduction, particularly in mature basins, and the continuing low oil price our sector must respond and adopt emerging technologies and leverage the power of automated processes to ensure a long term sustainable future.  TRT is the latest tool in our continuous drive to deliver operational excellence for our customers.”

The first of Peterson’s clients to use TRT is Wintershall. Rob Molenaar, logistics superintendent, added: “A focus on collaboration and genuine team work, combined with logical and innovative thinking is what is needed within the industry at this time. 

“Peterson has taken great steps in this direction particularly through the creation of vessel sharing initiatives and pioneering technology concepts and we see this tool as a big step towards greater efficiency in the offshore supply chain.”  

Local businessman scoops Northern Star Business award - 28/09/2015

Local businessman scoops Northern Star Business award

Lubbers Logistics BV, international logistics specialists for the upstream oil and gas industry, is celebrating today after its UK Sales Manager, Nick Latham scooped the Rising Star award at the highly anticipated Northern Star Business Awards in Aberdeen last night. 

Nick was commended for showing outstanding potential and a proven impact on contribution within the company. 

Nick joined Lubbers Logistics almost four years ago as a sales executive and quickly took on the role of UK Sales Manager at the young age of 25. In his time at Lubbers he has proved instrumental in growing the company in the UK and become an integral part of the international team. 

The customer-focused approach that Nick takes has enabled him to build a large network of contacts within the oil and gas industry and his ‘can do’ attitude internally, has proved indispensable. He has successfully developed his customer base over the last three years to significantly grow business in the UK entity for Lubbers Logistics BV.

Nick commented: “I am ecstatic to have been recognised in the Rising Star category at this year’s Northern Star Business Awards. I would not be here without the support and guidance from the fantastic team at Lubbers Logistics.”

On top of his daily job, Nick has also played a huge role in the support of local charity Friends of Anchor with various fundraising events throughout the year. 

Thursday, 24 September 2015

MORGAN ADVANCED MATERIALS IN FULL FLOW WITH ULTRASONIC TRANSDUCERS FOR GAS FLOW MEASUREMENT - 24/09/2015

MORGAN ADVANCED MATERIALS IN FULL FLOW WITH ULTRASONIC TRANSDUCERS FOR GAS FLOW MEASUREMENT

Morgan Advanced Materials is set to launch a new Ultrasonic transducer for measurement within the residential and industrial gas metering sector, optimising energy efficiency by offering customers greater transparency of energy consumption.

Drawing on its world-leading expertise in sensor and transducer technology, this latest development from Morgan boasts unrivalled measuring precision, making it ideal for use in industrial flow sensing. With its pioneering use of solid state technology, this transducer offers greater accuracy over time compared to alternative technologies based on moving parts which, when continually subjected to pressure, are vulnerable to wear and tear, impacting on measurement accuracy. An additional benefit of using ultrasonic technology is that meter readings can be taken wirelessly, providing convenience and ease of use for the end user.

To put this technological advancement into perspective, the new model has five times the sensitivity of its predecessor, an increase of 14db, and can withstand pressures of up to 100bar without compromising on accuracy.

Ewan Campbell of Morgan Advanced Materials commented: “Once again, Morgan is increasing sensitivity and pushing boundaries in terms of measurement performance in high-pressure gas pipelines. Our transducers are ideal for measuring highly attenuative materials such as high concentration methane, accurately and consistently, over a long period of time. By equipping customers with the means to accurately monitor energy consumption, they will be able to regulate energy usage and reduce energy-related expenditure in the process.“ 

FJORDS PROCESSING CEO PREDICTS NEW OPPORTUNITIES FOR THE OIL & GAS INDUSTRY - 24/09/2015

FJORDS PROCESSING CEO PREDICTS NEW OPPORTUNITIES FOR THE OIL & GAS INDUSTRY

Major oil and gas players will emerge from the global downturn leaner and greener sparking a new boom for firms in the supporting industries, a respected industry CEO predicts.

Rune Fantoft said the number one priority coming across from operators was a desire to find and secure new efficiencies.

Extending the life of fields, working equipment and technology longer and smarter and delivering on environmental improvements, have all risen closer to top of the industry’s business agendas.

And far from generating further crisis, he believes restructuring will create new opportunity for the industry to strengthen for the future.

He said that was already delivering a wave of new interest for firms like his, Fjords Processing, from companies seeking to tap into their well of expertise in helping maximise returns.

“I see great opportunities for companies like Fjords Processing who are well positioned during the downturn”, he said.

“It is an attractive proposition to field operators at a time when they are particularly dealing with the pressures of curtailed capital spending and profits.”

Companies such as Fjords are among the few in the sector offering a full portfolio of services across both new field developments, but increasingly brownfield sites and production optimisation.

The big players are looking at such firms to help them generate new cash flows for low cost, while also filling potential skills gaps created during the recasting of business models and reduced investment.

But it is the ability of the service industry to respond rapidly and tailor solutions that will deliver returns so quickly that he says is seeing a huge lift in what is becoming an increasingly important sector.

By way of proof, Fjords has just signed a raft of three new Brownfield contracts in recent weeks including in central North Sea, Qatar, Australia worth over $35 million. That comes on top of previous announcements in July of a triple contract win for the Johan Sverdrup development, also in the North Sea.

Such confidence is further evidence that major companies are increasing turning to service providers to deliver end-to-end solutions for them, creating potentially huge new growth streams for the sector.

Mr Fantoft explained: “Operators want to produce more oil even though they don’t want to invest that much into production. Our competitors do not have our range of solution capabilities and consequently we will become a more dominant force in that part of the industry.

“Our capability to be a strategic partner on the full journey, from the drawing board right through the delivery of bespoke solutions to excellent aftercare services, puts us in a unique position.”

The on-going contract in the North Sea, in which Fjords has designed and supplied produced water treatment and sulphate removal unit (SRU) packages in a single module for a major operator, demonstrates its ability to package multiple technologies to save on footprint, weight and cost.

Having one firm taking end-to-end responsibility also increases the project’s efficiency and reduces risk for the client using a single interface rather than several.

That allows them to integrate their expertise, analytical facilities and technology and validate the results before implementing the required solution.

“In other words, we don’t just tell the client what they need to do, we do it and that’s something the customers appreciate in today’s economic climate.”

His comments come after the latest annual economic impact report from trade body Oil and Gas UK confirmed the trend of companies looking at ways of improving performance and efficiency.

Oil and Gas UK’s economic director Mike Tholen said firms were showing clear “commitment to improving cost and efficiency” during challenging times.

The latest ICAE/Grant Thornton UK Business Confidence Monitor (BCM), also predicted an increase in confidence and investment. It suggests further recovery in the oil and gas sector by 2017.

Fjords Processing was among more than 1,500 global suppliers attending the recent Offshore Europe 2015, the largest event of its kind in the region.

Wednesday, 23 September 2015

LITRE METER LAUNCHES UNIQUE NEW FLOW INDICATION DISPLAY - 23/09/2015

LITRE METER LAUNCHES UNIQUE NEW FLOW INDICATION DISPLAY

UK Flowmeter specialist Litre Meter (www.litremeter.com) has launched a new, state-of-the-art lightweight flow indication display. Unlike other similar instruments, however, this device is unique – it is 2-wire, suitable for hazardous areas, HART compatible and has a 316 stainless steel enclosure, meaning it is likely to become a very popular application in the oil and gas industries, particularly for chemical injection systems.

One of the Smallest Flow Displays on the Market
The newly-launched application is the latest iteration of Litre Meter’s FlowPod; but measuring in at just two thirds of its predecessor’s diameter, this new model has instantly become one of the smallest flow displays available.

It isn’t just the size that’s changed – the new, compact model includes a range of additional functions, due to high demand from existing users of the earlier model. It can now display flow rate, total flow and analog rate. Plus, the new backlit display – which features high contrast ratio large flow rate indication and totalizer indication – means users can easily check the reading even at distance and in poor light conditions.

The model’s display features now include a five-digit rate display which gives the real time flow rate, flow range usage, plus the option to display flowrates and totals in multiple units. Its removable memory card allows for custom programming, and it includes 4-20 mA, HART, and pulse outputs as standard.

Non-Intrusive Calibration
There is no need to remove the FlowPod from where it is installed when switching calibration modes – the new FlowPod comes with data logging capabilities, which enable recalibration to be tailored to the actual working flow rate of the meter. This also helps users to avoid difficult on-site calibration curve changes.

Of course, all FlowPods are calibrated at the factory – for field recalibration, most customers will be able to use a HART programmer, or remove the memory card and use a laptop. Where this isn’t possible, the integrated magnetic switches allow for simple programming and menu selection, meaning it can be programmed without even powering down.

Slim, Flexible, Improved & Approved
The new FlowPod is housed in a slim, four-inch diameter stainless steel enclosure, and can be directly mounted to the flowmeter, or remote-mounted using suitable armoured signal cable or conduit. It can be adjusted to any angle, and its casing is explosion proof, and approved by ATEX, IECEx and CSA (USA & Can).

More oil from Gullfaks - 23/09/2015

More oil from Gullfaks

One of the major cash cows on the Norwegian shelf, the Gullfaks field, which has been producing for nearly 30 years, is facing further investments to boost production and extend the field’s lifetime.
The Norwegian Petroleum Directorate (NPD) has now submitted its assessment of the amended Plan for Development and Operation (PDO) for Gullfaks, including Shetland/Lista phase1, to the Ministry of Petroleum and Energy.

This concerns production from the Shetland group and Lista formation, which are situated above the actual main reservoir. Test production has already been under way for a few years. It is expected that 20 million barrels can be produced during this phase from Shetland/Lista. The reason for an amended plan is that production from Shetland/Lista was not included in the original development plan approved by the Storting in 1981.

According to the new plan, NOK 1.8 billion will be invested in reusing existing wells on the Gullfaks field for production from Shetland/Lista.

Shetland/Lista was originally not considered to be a reservoir, but subsequent developments have shown that recoverable oil is present. These zones, which are above the actual main reservoir on Gullfaks, are under natural high pressure, which makes it challenging to drill wells on Gullfaks. Production from Shetland/Lista could thus make it easier to drill future wells on the Gullfaks field.

Extensive amounts of data will also be collected, which may provide a basis for subsequent phases of production from Shetland/Lista, for example through pressure support.

Assistant director Tomas Mørch in the NPD (Development and operations – North Sea), is pleased that Shetland/Lista is being further developed. This will contribute to improved recovery on Gullfaks, and production from Shetland/Lista will make it possible to increase oil production in the field’s main reservoir.

Domestic nano-products can be used in Gazprom’s eastern projects - 23/09/2015

Domestic nano-products can be used in Gazprom’s eastern projects

Alexey Miller, Chairman of the Gazprom Management Committee and Anatoly Chubais, Chairman of the RUSNANO Executive Board had a regular joint meeting today at the Gazprom headquarters to consider the use of innovative products at Gazprom’s industrial facilities.

Attending the meeting were Members of the Gazprom Management Committee, heads of the relevant units and entities of Gazprom and RUSNANO as well as representatives of nanotech companies.

The meeting discussed the joint actions on estimating the feasibility and applicability of composite pipes and fasteners by Gazprom. The decision was made to go ahead with developing specifications for these pipes and components to be applied at Gazprom’s gas pipelines. The specifications will act as a basis for the development of pilot samples. Successful tests will result in laying pilot gas pipelines.

Future application of off-the-shelf composite pipes for water pipelines, sewage networks, upstream and downstream pipelines is under thorough consideration. For instance, Gazprom Neft put on trial the pipes planned for pilot application at Gazprom’s power generating facilities.

The parties discussed the introduction of domestic nano-products, including those produced by RUSNANO-owned companies, into Gazprom’s projects being part of the Eastern Gas Program and agreed to proceed with this activity.

Tuesday, 22 September 2015

Statoil Brazil awards Peregrino OMM contract to Wood Group - 22/09/2015

Statoil Brazil awards Peregrino OMM contract to Wood Group 

On behalf of the Peregrino licence partners, Statoil is awarding a contract to Wood Group to provide four-year operations and maintenance for our two wellhead platforms (Alpha and Bravo) and modification services for both units and the FPSO Peregrino.
Bilde

The contract’s scope includes offshore services and covers all production processes and equipment except drilling services and introduces a new operating model for the field, as for the first time the company is bundling all these services in one single contract in order to boost integration and simplify the contract management. 

“We have decided to group these contracts in line with our corporate strategy of simplification, cost optimization and production efficiency. We have been working closely with Wood Group in Peregrino field and we look forward to strengthening our partnership for the next four years”, says Pål Eitrheim, senior vice president for Development Production International South America and Brazil Country Manager. 

Wood Group has been operating the two wellhead platforms since 2009 and has supported the Peregrino project throughout its development. 

“The bundling of the contracts will bring significant cost savings to Statoil Brazil, in addition to simplification to our operations. It’s essential to take the best of what the market can offer to us and further strengthen the relationship with our key suppliers”, says Jon Arnt Jacobsen, chief procurement officer of Statoil. 

OptaSense named finalist in Global Pipeline Awards - 22/09/2015

OptaSense named finalist in Global Pipeline Awards

Unique use of acoustic sensing by world leader provides effective leak and intrusion detection

OptaSense, a QinetiQ company and the global leader in Distributed Acoustic Sensing (DAS) has been recognised for its unique contribution to effective pipeline leak and intrusion detection by being shortlisted for a prestigious international award.

The company has been recognised in the ASME Pipeline Systems Division Global Pipeline Awards for the innovative use of its award-winning DAS system on Columbia’s Bicentennial oil pipeline.

The judging panel recognised OptaSense’s unique use of a single fibre system to provide both leak detection and intrusion detection on the country’s largest pipeline. The 235Km first phase of the pipeline was completed in 2012 and has a diameter of 36-42 inches with the capacity of 450,000 barrels per day (bpd) of crude.

The integrated DAS solution works across multiple functions via a single fibre-optic cable that effectively “listens” to the pipeline in order to provide detailed data about its current status. Any changes to the condition of the pipe are fed back through an interrogator unit in real time, allowing users to identify and address issues early and maintain the highest level of pipeline integrity and product throughput.

Leak and intrusion detection are vital to maintaining pipeline integrity and production maximisation in the oil and gas industry. The pipeline was closed last year due to third party attacks on it, costing the Columbian economy thousands of barrels per day in lost deliveries.

OptaSense executive director Magnus McEwen-King said: “This award not only recognises the innovative use of fibre but also the engineers of Ecopetrol and OptaSense who have jointly worked to deliver real improvements to the integrity management process of the Bicentennial pipeline.

“This nomination is a further acknowledgment of our leading position in South America, and highlights our commitment to continued growth in the region. Our award-winning technology has a proven record of reducing the costs of asset ownership and providing life-long intelligence through highly effective monitoring, thereby reducing incidents and extending asset life.”

The annual awards ceremony aims to recognise pipeline technology innovation processes in phases such as: research laboratory, field applications, technology incubators, and development of markets for new products, and is open to all companies.  The winners will be announced at the awards ceremony held on Thursday 24 September 2015. The four other finalists are: Rosen Group, GMC Inc., Subsea 7, and LABMETRO, CENPES Petrobas Research Center. 

Monday, 21 September 2015

LITRE METER LAUNCHES NEW INSTRUMENTATION DISPLAY - 21/09/2015

LITRE METER LAUNCHES NEW INSTRUMENTATION DISPLAY

UK flowmeter specialist Litre Meter ( www.litremeter.com ) has launched a unique 2-wire state-of-the-art lightweight flow indication display suitable for hazardous areas. It is HART compatible and has a 316 stainless steel enclosure. It is expected to find widespread application in the oil and gas industries, particularly for chemical injection systems.

At just two thirds the diameter of its previous iteration the new FlowPod is one of the smallest flow displays on the market. It is an evolution of the existing large display to provide additional functionality which has been requested by users.

This functionality includes the facility to display flow rate, total flow and analog rate. The backlit display, which features high contrast ratio large flow rate indication and totalizer indication, enables the display to be read at distance in poor light conditions.

Display features include five-digit rate display giving the real time flow rate, the option to display flowrates and totals in many different units and flow range usage. It has a removable memory card for programming and offers 4-20 mA, HART and pulse outputs as standard.

Calibration modes can be easily switched without having to remove the FlowPod from the installation or having to perform difficult on-site calibration curve changes. Data logging capabilities enable recalibration to be tailored to the actual working flow rate of the meter.

All FlowPods are calibrated at the factory. For field recalibration most customers will be able to use a HART programmer or remove the memory card and use a laptop. Where this is not possible the integrated magnetic switches allow for simple programming and menu selection. This means that it can be programmed without having to power down.

The new FlowPod can be supplied either direct-mounted to the flowmeter or remote-mounted using suitable armoured signal cable or conduit. The display can be adjusted to any angle.

The FlowPod is housed in a slim four-inch diameter explosion proof stainless steel enclosure, and is ATEX, IECEx and CSA (USA & Can) approved. 

Tata Steel awarded multi-million pound contract on Maersk Culzean project - 21/09/2015

Tata Steel awarded multi-million pound contract on Maersk Culzean project

Tata Steel has been awarded a multi-million pound contract for the Maersk Culzean project located in the UK central North Sea – one of the largest discoveries in the region in the last 10 years. 

The company will be responsible for providing more than 18 thousand tonnes of carbon steel welded line pipe with the core element of the scope of supply encompassing a 22” (53km) gas export pipeline which will tie into the existing Central Area Transmission System (CATS). 

The gas export line will be manufactured at Tata Steel’s UOE LSAW pipe mill located in Hartlepool, UK with BSR Pipeline Services, a joint venture with Tata Steel, providing the coating services. 

Richard Broughton, commercial manager, exploration and production, Tata Steel, commented: “We worked very closely with Maersk, to ensure that the stringent technical requirements were understood.  Our technical capability to manufacture low temperature pipelines with tight dimensional control is well proven, and I am confident that this was a key consideration in the tender evaluation.  Tata Steel has a proven global track record of managing complex project packages. 

“Tata Steel has executed projects of this nature in the past with extreme precision and accuracy, ensuring achievement of project objectives and client goals. We are excited to be working with Maersk and Subsea7 to ensure the same outcome on this project.”

Work is due to start in September 2015 with an overall project duration for Tata Steel of 18 months.

ESS Offshore celebrates fourth consecutive health and safety award win - 21/09/2015

ESS Offshore celebrates fourth consecutive health and safety award win

ESS Offshore Support Services, part of Compass Group UK & Ireland has won a gold award for its approach to occupational health and safety in a scheme run by accident prevention charity, the Royal Society for the Prevention of Accidents (RoSPA).

This is the fourth consecutive time the firm has picked up the RoSPA President’s (13 consecutive Golds) Award for Occupational Health and Safety, presented during the annual ceremony at the Glasgow Hilton Hotel last night (September 17).

The RoSPA awards are internationally recognised by an array of industry sectors and ESS will add its latest accolade to a string of wins achieved in the last year alone including gold and silver at the prestigious Villeroy & Boch World Cup.

Allan Errington, ESS Offshore Support Services HSE manager, said: “We are extremely proud to have been awarded this accolade from RoSPA.  People are at the heart of what we do and their safety is our utmost priority. 

“This award celebrates our continued commitment to providing the highest possible safety standards and highlights our focused approach to workplace safety through workforce engagement and involvement.”

David Rawlins, RoSPA’s awards manager, said: “The RoSPA Awards encourage improvement in occupational health and safety management. Organisations that gain recognition for their health and safety management systems, such as ESS Support Services Worldwide, contribute to raising standards overall and we congratulate them.”

Thursday, 17 September 2015

Tata Steel awarded multi-million pound contract on Maersk Culzean project - 17/09/2015

Tata Steel awarded multi-million pound contract on Maersk Culzean project

Tata Steel has been awarded a multi-million pound contract for the Maersk Culzean project located in the UK central North Sea – one of the largest discoveries in the region in the last 10 years.

The company will be responsible for providing more than 18 thousand tonnes of carbon steel welded line pipe with the core element of the scope of supply encompassing a 22” (53km) gas export pipeline which will tie into the existing Central Area Transmission System (CATS).

The gas export line will be manufactured at Tata Steel’s UOE LSAW pipe mill located in Hartlepool, UK with BSR Pipeline Services, a joint venture with Tata Steel, providing the coating services.

Richard Broughton, commercial manager, exploration and production, Tata Steel, commented: “We worked very closely with Maersk, to ensure that the stringent technical requirements were understood.  Our technical capability to manufacture low temperature pipelines with tight dimensional control is well proven, and I am confident that this was a key consideration in the tender evaluation.  Tata Steel has a proven global track record of managing complex project packages.

“Tata Steel has executed projects of this nature in the past with extreme precision and accuracy, ensuring achievement of project objectives and client goals. We are excited to be working with Maersk and Subsea7 to ensure the same outcome on this project.”

Work is due to start in September 2015 with an overall project duration for Tata Steel of 18 months.

The first subsea gas compression plant in the world on line, a step change in subsea technology - 17/09/2015

The first subsea gas compression plant in the world on line – a step change in subsea technology 

Statoil and its partners this week put the first subsea gas compression facility on line at Åsgard in the Norwegian Sea. Subsea compression will add some 306 million barrels of oil equivalent to total output over the field’s life .

This subsea technology milestone opens new opportunities in deeper waters, and in areas far from shore.

This is one of the most demanding technology projects aimed at improving oil recovery.  We are very proud today that we together with our partners and suppliers have realised this project that we started ten years ago,” says  Margareth Øvrum, Statoil’s executive vice president for Technology, Drilling and Projects.

Recovery from the Midgard reservoir on Åsgard will increase from 67 percent to 87 percent, and from 59 percent to 84 percent from the Mikkel reservoir.  Overall, 306 million barrels of oil equivalent will be added.

“Thanks to the new compressor solution we will achieve increased recovery rates both at Midgard and Mikkel, extending the reservoirs’ productive lives until 2032,” says Siri Espedal Kindem, senior vice president for Åsgard operations.

Demanding technology development

As a field gets older, the natural pressure in the reservoir drops. In order to recover more oil and gas, and get this to the platform, compression is required. The closer to the well compression takes place, the more oil and gas can be recovered.

Traditionally compression plants are installed on platforms or onshore, but this plant is located in 300 metres of water.

Due to the challenging location, quality in all parts of the project has  been essential, and will help ensure high regularity, maximum recovery and robust production.

The project started in 2005, and the plan for development and operation (PDO) was approved in 2012.

An estimated eleven million man-hours have been spent from the start until completion. More than 40 new technologies have been developed and employed after prior testing and verification. Some of this work has taken place at Statoil’s Kårstø laboratory in Western Norway.

Overall, project cost were just above NOK 19 billion. Many small and big suppliers have helped to develop the sophisticated underwater compressor system.

Establishing the necessary support functions onshore has been an important and substantial part of the project. A spare compression train will be stored in custom designed halls at the onshore supply base Vestbase in Kristiansund.

“High-quality, regular maintenance  of the subsea modules will also be performed here, helping  ensure operational excellence for Åsgard,” says Espedal Kindem.

Technology for the future, and new potentials

The Midgard and Mikkel gas reservoirs have been developed using subsea installations. The two gas compressors now installed on the seabed are located close to the wellheads.

Moving the gas compression from the platform to the wellhead substantially increases the recovery rate and life of the fields. Prior to gas compression, gas and liquids are separated out, and after pressure boosting recombined and sent through a pipeline some 40 kilometres to Åsgard B.

In addition to improving recovery subsea gas compression will be more energy efficient than the traditional topside solution. The technology reduces significantly energy consumption and CO2 emissions over the field’s life.

Today almost 50 percent of Statoil’s production is recovered through some 500 subsea wells. Statoil’s subsea expertise is essential to successful production efficiency improvement and increased oil recoveryefforts.

“Subsea gas compression is the technology for the future, taking us a big step closer to our ambition of realising a subsea processing plant, referred to as the subsea factory”, says Øvrum.

Such a plant will facilitate remotely controlled hydrocarbon transportation.  Current topside operations will thus be moved to the seabed, allowing oil and gas to be recovered that would not otherwise be profitable. This is an important element of increased recovery on the Norwegian continental shelf.

Small oil discovery southwest of the Njord field in the Norwegian Sea - 17/09/2015

Small oil discovery southwest of the Njord field in the Norwegian Sea - 6406/12-4 S and A

VNG Norge AS, operator of production licence 586, is in the process of completing the drilling of wildcat wells 6406/12-4 S and 6406/12-4 A.

Well 6406/12-4 S was drilled approx. 33 kilometres southwest of the Njord field in the southern part of the Norwegian Sea and approx. 1.7 kilometres southeast of discovery well 6406/12-3 S (Pil).

The primary exploration target of well 6406/12-4 S was to prove petroleum in Upper Jurassic sandstones in a southwestern segment, which is adjacent to the 6406/12-3 S discovery (Pil). The well encountered an approx. 590 metre thick unit of Upper Jurassic rocks, 20 metres of which of are sandstone (the Rogn formation) with good reservoir quality. Preliminary estimates of the size of the discovery range between two and five million standard cubic metres (Sm3) of recoverable oil equivalents. The licensees will consider the discovery in conjunction with other nearby discoveries as regards a possible future development.

The secondary exploration target was to prove petroleum in Upper Jurassic rocks (sandstone in the Intra Melke formation), the extent, thickness and properties of the reservoir rocks, as well as depth to hydrocarbon contacts. The well encountered 368 metres of sandstone in the Intra Melke formation of varying quality and with traces of oil.

The objective of well 6406/12-4 A was to prove petroleum in Upper Jurassic reservoir rocks (sandstone in the Intra Spekk and Intra Melke formations) in a southern segment adjacent to the 6406/12-3 S discovery (Pil). Well 6406/12-4 A encountered about 20 metres of Intra Spekk sandstone and 515 metres of reservoir rocks in the Intra Melke formation, both with poor reservoir properties. The reservoir contains only traces of hydrocarbons. The well was classified as dry.

Extensive data acquisition and sampling have been carried out. These are the fourth and fifth wells to be drilled in production licence 586, which was awarded in APA 2010.

6406/12-4 S was drilled to measured and vertical depths of 4318 and 3832 metres below sea level respectively, and was terminated in the Melke formation in the Upper Jurassic.

6406/12-4 A was drilled to measured and vertical depths of 4058 and 3799 metres below sea level respectively, and was terminated in the Melke formation in the Jurassic. Water depth at the site is 319 metres.

The wells will now be permanently plugged and abandoned.

Wells 6406/12-4 S and A were drilled by the drilling facility Transocean Arctic which now will drill 6406/12-5 S in a northern segment adjacent to the discovery 6406/12-3 S (Pil). 

Wednesday, 16 September 2015

ExxonMobil to Produce Flagship Mobil 1 Synthetic Engine Oil in Singapore - 16/09/2015

ExxonMobil to Produce Flagship Mobil 1 Synthetic Engine Oil in Singapore

New facility will be only Asia Pacific location to manufacture world’s leading synthetic engine oil brand

Additional capacity supports growing demand from automotive manufacturers and motorists
ExxonMobil is expanding its operations in Jurong to produce synthetic lubricants, including Mobil 1TM, the company’s flagship synthetic engine oil. The expansion will further strengthen the company’s manufacturing capabilities and ability to meet the growing demand for ExxonMobil synthetic products in the Asia Pacific region.

When completed in the second half of 2017, the facility will be the only plant in the Asia Pacific producing Mobil 1, the world’s leading synthetic motor oil. The facility will be one of five locations where Mobil 1 is produced.

“Mobil 1 is ExxonMobil’s most advanced synthetic engine oil,” said Bennett Hansen, Asia Pacific lubricant sales director at ExxonMobil. “Adding Singapore to our network of Mobil 1 manufacturing facilities will ensure customers’ needs are met well into the future. The new Singapore facility will employ innovative manufacturing technologies, demonstrating the company’s commitment to bringing premium products and technology to the market.”

The lubricant plant, strategically located next to ExxonMobil’s manufacturing site in Jurong, adds to the company’s increasing lubricants and specialties production capabilities in Singapore. The company, which has operated in Singapore for more than a century, has continued to grow its integrated refining and petrochemicals manufacturing site. The new production facility is in addition to the company’s recently announced grease manufacturing investment.

“ExxonMobil’s new synthetic lubricants plant will create yet another competitive advantage for the company and it will complement the existing lubricant additives industry here,” said Damian Chan, Singapore Economic Development Board’s executive director for energy and chemicals. “This investment reflects the industry’s push toward higher value-added manufacturing operations to meet growing middle-class demand for more sophisticated products in Asia.”

Gan Seow Kee, ExxonMobil Asia Pacific chairman and managing director, said: “The decision illustrates ExxonMobil’s continued confidence in Singapore and the Asia-Pacific economy.

“Both the synthetic lubricants and grease investments underscore the company's ongoing commitment to disciplined long-term investments that improve our competitiveness and bring value to the country.”

According to a recently completed analysis by Kline & Company, Asia-Pacific demand for passenger car synthetic engine oil is expected to grow more than eight percent between 2014 and 2024. Globally, more and more vehicle manufacturers are choosing synthetic oil for their vehicles. Currently, more than 35 vehicle models including those produced by Porsche, Mercedes AMG and General Motors, roll off the factory line featuring Mobil 1.

Virtus Oil and Gas Encounters Oil Shows at Lone Pine 34-11-5 Test Well - 16/09/2015

Virtus Oil and Gas Encounters Oil Shows at Lone Pine 34-11-5 Test Well

Company to Evaluate Well Findings, Protect the Wellbore, and Plan its Next Well

Virtus Oil and Gas Corporation (OTCBB: VOIL) ("Virtus" or "the Company") is pleased to announce it has encountered oil shows after penetrating the 1st Navajo Formation while drilling the Lone Pine 34-11-5 test well to a final depth of 5,362 feet.

Mud log with oil shows from the Virtus Lone Pine 34-11-5 test well.
Over the last few weeks of drilling, the Company has discovered 200 feet of oil traces in the Navajo Formation that were consistent with Virtus' seismic interpretations done in the last year. Based on the initial data collected from oil traces, log files and mud logs, the Company is excited with the findings from this first pilot (or Test) well.

Following the results acquired to date at the Virtus Lone Pine 34-11-5 test well, the Company will now commence the evaluation process of all data sources and once complete will move forward with the next stage of the drilling program once all expert opinions are gathered.

Mike Roberts, Engineer at Virtus, said: "Based upon geologic samples and the formation tops encountered, a decision was made to drill the well shallower than originally planned. During the course of drilling the drill bit continued to deviate and build angle more than expected due to a fault in the subsurface. We decided it was better to drill a shallower pilot well and identify all potential formation tops and correlate this with the seismic the Company has purchased and interpreted in 2014. The data acquired from this test well is valuable and it is encouraging that oil traces were discovered at the Virtus Lone Pine confirming that is was not a dry well."

Rupert Ireland, CEO of Virtus, said: "The initial test well at Virtus Lone Pine has gone to plan and we were most encouraged to discover oil traces for over 200 feet. We now have a much greater understanding of this complex thrust area and are confident of what we have to do when we drill our second well later this year or early part of next year. We now know where the fault line is and that the Kaibab Limestone is much shallower than expected meaning we won't have to drill the next well to 12,000 feet. The area of interest, which will be targeted with the second well, has been re-evaluated and determined by geologic analysis to be close by and within a few hundred feet, but is still a small distance in another direction from the surface location. The results from this test give us confidence to move forward at the Parowan Project. Energy Drilling, and Mike Roberts, our Company Engineer, did a superb job in executing the company's mission in this pilot well. Gary Smith, Owner of Energy Drilling, offered the best value bid with his Rig 8 and we look forward to working with him again on future projects. The second well, which will not be a science pilot well, but more an attempt for production, will be ably supported by directional drilling tools that can handle the high angle area zones and navigate the fault lines more precisely."  

Brett A. Murray, COO of Virtus, said: "We are excited to find traces of oil and also to see the large buildup of pressure pushing our drill bit directionally before we pulled back and entered the second Navajo formation. The difficulty in this prospect has been the well control with very few wells penetrating the formations in this area and knowing we had various faults as shown on our seismic. To keep the integrity of the well bore intact, VOIL has added temporary plugs to the Virtus Lone Pine Drilling hole on Saturday 12th September and the wellhead will have a blind flange installed on the 11 x 3000 psi connection which will suffice for a secure temporary abandonment status until operations are resumed. The deepening of this well is an viable option but the scientist will confirm if the wellbore was on track to penetrate the best production zones due to lack of directional bit."

Ryan Cox, Geologist of RPM Consulting who has been one half of the team of On Site Geologists working on behalf of Virtus Oil and Gas at Virtus Lone Pine along with fellow Geologist and President of RPM,  Joseph Large, believe the deeper Kaibab Limestone, the target of the second well, may have greater oil potential than the shallower Navajo.

Cox said: "From the depth of 4,470 feet to 4,670 feet we encountered very trace evidence of hydrocarbons immediately upon entering the Navajo Sandstone.  With a proper cap rock, the Navajo has the potential to be a highly productive reservoir that rivals Middle Eastern sands.  We have much higher hopes of the older Kaibab Limestone trapping hydrocarbons as the permeability is less than the Navajo Sandstone and based on seismic data appears to be less affected by the younger fault system."

Virtus Oil and Gas will now meet with RPM and Gustavson Associates and compare their Geological Findings with the Gustavson Report of October 2014 and Seismic Interpretations prepared by VOIL Geologist Dr. Bob Benson.

Ireland concluded: "This has been an exciting 12 months for Virtus Oil and Gas, during which time the company has exited being a shell status company, to now being a Public Oil and Gas Exploration and Operating Company," Ireland said. "We look forward to taking the next steps for progressing our Parowan Project toward commerciality."

Contract award for Johan Sverdrup power cables - 16/09/2015

Contract award for Johan Sverdrup power cables 

Statoil has, on behalf of the Johan Sverdrup partnership, awarded a contract to ABB AB in Sweden for fabrication and installation of two high-voltage cables supplying power from shore to the Johan Sverdrup field.
Johan Sverdrup

The contract is an EPCI contract covering engineering, procurement, fabrication, installation and testing of two high-voltage power cables and a fibre-optic communication cable to the Johan Sverdrup field centre from shore.

The high-voltage cables are 200 kilometres long and designed for a supply capacity of 100 MW/80 kV. This will cover the power need for the first phase of the Johan Sverdrup field development, which is scheduled for start-up late in 2019.

The contract also covers options for delivering high-voltage cables from shore to the Johan Sverdrup field to meet the power requirement of a full development of the Johan Sverdrup field as well as the Edvard Grieg, Ivar Aasen and Gina Krog fields on the Utsira High.

The total contract value is NOK 700 million, plus options.

Fabricated at ABB AB’s plant in Karlskrona, the high-voltage cables will be laid from Haugsneset in Tysvær municipality north of Stavanger to the Johan Sverdrup field centre on the Utsira High. The power cables will be pulled up to the riser platform at the Johan Sverdrup field centre.

The cables will be buried into the seabed or covered by rocks, as required.

This contract is one of the three major contracts covering the land-based power supply project. The first contract has already been awarded to ABB in Norway for delivery of high-voltage direct current transformer equipment to the riser platform at Johan Sverdrup and at Haugsneset.

The last contract covers all construction work related to the alternating current cable to be laid from Kårstø to Haugsneset and the entire onshore converter station. The contract for the onshore construction work is being evaluated and is expected to be awarded this autumn.

The Johan Sverdrup oil field will be operated by land-based power from production start in late 2019.

The first phase of the Johan Sverdrup field development will also include all the preparations needed for land-based power supply for a full Johan Sverdrup development as well as other fields on the Utsira High by 2022.

The Johan Sverdrup field partners: Statoil 40.0267% (operator), Lundin Norway 22.6%, Petoro 17.36%, Det norske oljeselskap 11.5733% and Maersk Oil 8.44%.

Tuesday, 15 September 2015

Dejour Issues Kokopelli Project Update - 15/09/2015

Dejour Issues Kokopelli Project Update

Deep Mancos Discovery 14 Stage Completion Highlights Successful Operations 
Dejour Energy Inc. (NYSE MKT:DEJ) (TSX: DEJ) ("Dejour" or the "Company"), an independent oil and gas exploration and production company operating in North America's Piceance Basin and Peace River Arch regions, today announced an operational update for its project in NW Colorado.

On Kokopelli Pad 21B, Dejour and its operating partner successfully drilled, cased and completed seven Williams Fork wells (Federal 14-15-1-21 through Federal 14-15-8-21) and a single vertical 13600' Mancos discovery well (Federal 14-15-7-21) as contemplated in the original 2014 drill program. The deep Mancos discovery well completion incorporated 14 stages to best assess the multi-zonal potential of the leasehold.

Logs of the Mancos section indicate the presence of gas throughout this deeper zone.
These wells are currently flowing back gas, oil and NGL’s directly into production lines with completion water safely deposited in the PWD well recently drilled and equipped for that purpose. Clean up should be substantially complete with cumulative daily production volumes accurately estimated by the end of the quarter.

Dejour owns a 25% working interest in this Kokopelli project. While the production from the liquids rich Williams Fork is very important to balance existing processing contracts, the successful establishment of a robust gas volume from the high pressure Mancos will dramatically enhance both the production profile and reserve life/value of the entire project

“We are pleased to report the successful completion of the twelve month development and exploratory drilling program executed at the Kokopelli project in NW Colorado.  The transformative event of the Mancos addition, making Kokopelli a true multi-zonal producing property, is the culmination of years of planning. We look forward to including this new production into our overall project profile and will provide a further update when sustainable flow rates are available,” stated Robert L. Hodgkinson, Chairman & CEO.   

Maersk Line signs contract with MeteoGroup for advanced SPOS Motions module for 140 container vessels - 15/09/2015

Maersk Line signs contract with MeteoGroup for advanced SPOS Motions module for 140 container vessels

MeteoGroup, a world leading weather business, has in partnership with ABB Combined with ABB’s Octopus motion-forecasting product, the Seakeeping module will allow Captains avoid routes where the ships motion thresholds are likely to be exceeded.

The combined service allows for more advanced and accurate route planning and an early response to adverse conditions when they are forecast. The collaboration will include advanced 3D modelling to calculate motions indicating a vessels likely response to weather conditions.

Business Unit Director Marine, at MeteoGroup, Mark White said: “Maersk are long time users of MeteoGroup’s SPOS (Ship Performance Optimisation System) and we are delighted that they have chosen to work with us and ABB in implementing SPOS Seakeeping across their vessels. This is a great vote of confidence in MeteoGroup’s ingoing program of innovation and product development.”

Monday, 14 September 2015

14/09/2015Smith Flow Control to Exhibit its Valve Safety Products at ADIPEC - 14/09/2015

Smith Flow Control to Exhibit its Valve Safety Products at ADIPEC

Recognising the importance of reducing downtime and associated costs while safeguarding workers, Smith Flow Control’s valve safety products streamline valve processes in the Oil & Gas industry while ensuring operator safety.

Smith Flow Control (SFC) will showcase its range of mechanical interlocks and cost-effective valve management systems at ADIPEC 2015 in Abu Dhabi from 9-12 November, 2015. This offers the chance for visitors to meet and discuss their valve operating problems with SFC experts at stand 8530A, covering all aspects of process safety, valve interlocking and valve management. 

SFC’s products greatly enhance safety and efficiency and are specified by the world’s biggest oil, gas and petrochemical companies. Its comprehensive range of process safety products reduce the scope for operator error and ensure safe continuous plant operation. Its range of key operated interlocks can also be customised to implement a safe sequence of events in any process activity.

Smith Flow Control will demonstrate its principal drive system that reduces work crew tasks to one man operations, the equivalent manpower of 5 men. EasiDrive is a cost effective, portable valve actuator; its continuous drive system allows an operator to easily open and close valves that require a high number of turns or are otherwise difficult to operate. EasiDrive prevents injury and saves time and manpower, keeping plant processes running smoothly and delivering significant cost savings.

TENDEKA ANNOUNCES TWO MAJOR CONTRACT WINS IN THE MIDDLE EAST - 14/09/2015

TENDEKA ANNOUNCES TWO MAJOR CONTRACT WINS IN THE MIDDLE EAST

Tendeka, the provider of completions systems and services to the upstream oil and gas industry, has announced two significant contracts for its zonal isolation and inflow control technology in the Middle East.

Following a highly successful initial contract period, Tendeka has been re-awarded the contract to supply PDO with swellable solutions for all fields in Oman. The $5m contract will span 5 years, with an optional two-year extension. Tendeka has been present in Oman since 2002 and has deployed over 4000 of its Swellfix packers for PDO since that time. The award win demonstrates Tendeka’s strength of position in the zonal isolation market for the Middle East and is testament to the consistent service and quality of its swellable technology.

In a separate award, and following work on previous contracts including fibre optic monitoring and both swellable and mechanical zonal isolation solutions, Tendeka will provide a major operator with inflow control device (ICD) completions and swellable packers in a deal worth up to $5m. The four-year contract will mark the first ICD installations for the major operator and will commence with the installation of three trial wells.

Derek Taylor, Tendeka’s Vice President for EMEAR, said: “The Middle East has always been a key region for Tendeka and the award of two major contracts builds on our previous successes here. In both cases our solutions will provide significant value to our clients and we look forward to working closely with them in the coming year to fully realise that value.”  

Tendeka has a comprehensive portfolio of open-hole completion technologies, which provide integrated solutions for inflow assurance, optimisation and control. These best in class technologies include liner hangers, a range of ICDs, metal mesh or wire wrap screens for sand or debris control, a multiple zonal isolation solutions, and integrated monitoring systems, with over 40,000 installed around the globe.

Tendeka’s full range of reservoir completion technologies can be deployed to solve issues in unconsolidated formations, carbonate reservoirs, tight and shale formations, heavy oil and high pressure high temperature environments, multi-horizon and multi-lateral wells, and production and injector applications.