InnovOil Issue 55 August 2017

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Bringing you the latest innovations in exploration, production and refining Issue 55

LIKE A ROLLING DRONE

Flyability’s Elios inspection drone Page 14

August 2017

SHIPPING OUT

Rolls-Royce tests the world’s first remote commercial vessel Page 6

EAGLE SOARING EOG on EOR Page 28

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August 2017

page 3

Inside A note from the Editor

5

Contacts:

World-first mission

6

Media Director Ryan Stevenson ryans@newsbase.com

DoE offers new funding

7

GE and Baker Hughes

8

Minox’s DryGas system

9

Rolls-Royce, Svitzer demonstrate first autonomous ship

Aid unconventional production

Media Sales Charles Villiers charlesv@newsbase.com

Merger finally completed on July 3

Kevin John kevinj@newsbase.com

Cost-efficient gas dehydration

Technology radar

Editor Andrew Dykes andrewd@newsbase.com

Outside the world of oil and gas

10

ROVs AND UAVs 13

NewsBase Limited Centrum House, 108-114 Dundas Street Edinburgh EH3 5DQ

Super collider

14

JFSE’s MultiROV

17

Flyability’s collision-resistant Elios drone

The first mass flow excavation package

Phone: +44 (0)131 478 7000

Fixed-wing vertical take off 19

www.newsbase.com www.innovoil.co.uk

SkyX pushes the limit

Design: Michael Gill michael@michaelgill.co.uk www.michaelgill.eu

Getting REMORA

20

Collaborative projects

24

Subsea-resident autonomous robot.

OGIC backs emergent robotics

J2 Subsea and BluHaptics 26 New agreement

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ction ations in exploration, produ Bringing you the latest innov

Resident experts

27

EOR in the Eagle Ford

28

ROV looks to make the best of both worlds

and refining August 2017

Issue 55

Harnessing such techniques in shale will face considerable challenges

Centrica’s Rough closure 30 LIKE A ROLLING DRONE

Flyability’s Elios inspection drone Page 14

The catalyst for the government to create an appropriate regulatory framework for gas storage

News in brief

SHIPPING OUT

Rolls-Royce tests the world’s vessel first remote commercial Page 6

ING EAGLE SOAR on EOR EOG

32

Contacts 38

Page 28

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page 5

A note from the Editor OF all the robotics technologies we look at, few seem to undergo the same level of innovation as ROVs and UAVs. Perhaps this is tied to the myriad sectors that inform remote vehicle development. Advances in communications, batteries, electrification, sensors and autonomy are all driving progress in different ways, lending this particular subset of the industry a momentum not seen elsewhere.

The potential for cost reduction too is a major factor.

Although ROVs can handle more subsea tasks than ever, and the use of aerial drones for topside inspection is now more commonplace, there are still gains to be made. On the seabed, engineers are working increasingly towards “resident” solutions – robots which can be permanently deployed to inspect and maintain their respective assets – as a way of dramatically reducing the need to send multiple vessels and crews offshore.

The same is true on land. In this issue, for example, we look at the solution proposed by Canadian start-up SkyX. Using a proprietary drone design – a hybrid between a quadcopter and a fixed-wing UAV – the company intends to establish an autonomous network capable of surveying hundreds of miles of pipelines, all without human intervention. The cost advantage of such a method compared with frequent visual inspection missions by road or by helicopter is substantial.

Elsewhere, we dig deeper into the modular autonomous ROV programme being developed by the Technical University of Denmark, dubbed REMORA, as well as our cover feature – a collision-resistant drone for inspecting enclosed indoor spaces, from Swiss firm Flyability. In addition, we look at innovations from JFSE, Saipem, Hydrason and more.

Not entirely outside the world of remotely operated robots, Rolls-Royce is working on even bigger plans.

This month saw it test the world’s first remotely operated commercial vessel, in the form of a tug boat in Copenhagen. As the technology gains traction and secures regulation, similar systems could soon be sending supplies to platforms and ports all over the world.

Elsewhere, we look at new technology-supporting grants available from the US Department of Energy, an innovative and space-saving gas dehydration solution proposed by Norway’s Minox Technology, the need for regulation around gas storage capacity, and gain insight into the dramatic production boosts secured by EOG Resources’ EOR programme in the Eagle Ford Shale.

For now, however, we wish our readers well during the typically quieter August period, and look forward to seeing many of you at Offshore Europe in September.

We are pleased to present the August issue of InnovOil.

Andrew Dykes Editor

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page 6

InnovOil

Rolls-Royce, Svitzer demonstrate first autonomous ship World-first mission sees remote ship piloted around Copenhagen harbour

I

N mid-2016 InnovOil spoke with RollsRoyce vice president of innovation for marine, Oskar Levander, about the future of autonomous shipping. Even then, his message was that the future is already here: “This is happening. It’s not if, it’s when.”

Little more than a year later, the engineering giant has proved its point. In late June, the company announced it had successfully demonstrated the world’s first remotely operated commercial vessel, in Copenhagen harbour. According to reports, the 28m vessel, operated by towage firm Svitzer, was piloted from its berth at the quay side in the harbour, undocked, turned 360°, and sailed to the Svitzer HQ, before docking again. It did so under operation from the vessel’s captain, sitting in a remote station inside a base at Svitzer headquarters.

The 132 DWT Svitzer Hermod tug is based on a Robert Allan ship design, and was built in Turkey at the Sanmar yard in 2016. It is equipped with a Rolls-Royce dynamic positioning system (DPS), which is also the main link to the operating remote controlled system. In addition to its software and positioning, the vessel is equipped with a pair of from Rolls-Royce MTU 16V4000 M63 diesel engines, each rated 2000 kW at 1800 rpm.

Remote operations are aided by a range of sensors across the vessel, which offer a number of different data inputs to help captains maintain an awareness of the vessel and its surroundings. The data is then transmitted securely to a so-called remote operating centre (ROC). According to RollsRoyce, this itself has also been designed to give a new perspective on the way in which vessels are controlled. “Instead of copying existing wheelhouse design the ROC used input from experienced captains to place the different system components in the optimum place to give the master confidence and control. The aim is to create a futureproof standard for the control of vessels remotely,” the company said.

Svitzer, Rolls-Royce and other project partners were present to witness the operation. Rolls-Royce president for marine Mikael Makinen remarked that: “We’ve been saying for a couple of years that a remotely operated commercial vessel would be in operation by the end of the decade.

Thanks to a unique combination of Svitzer’s operational knowledge and our technological expertise, we have made that vision a reality much sooner than we anticipated.”

Lloyd’s Register’s marine and offshore director, Nick Brown explained the agency’s role in the project: “With autonomous ships likely to enter service soon, we have already set out the ‘how’ of marine autonomous operations in our ShipRight procedure guidance as it is vital these technologies are implemented in a safe way and there is a route for compliance. Lack of prescriptive Rules was no barrier for “de-risking” the project and we provided assurance against LR’s Cyber-Enabled Ships ShipRight Procedure, whilst considering the safety implications associated with the first closed demonstration.”

Rolls-Royce and Svitzer have also signed an agreement to continue their cooperation to further test remote – and eventually autonomous – operations for vessels. It marks the latest in series the company has made, another notable instance being a memorandum of understanding signed with Cargotec to work together on autonomous systems for navigation and cargo on board container ships.

Last year, Oskar Levander concluded our interview by noting that: “In the beginning there were a lot of sceptical voices, but during the last year everyone is talking about it. More people are sure that it is coming, more companies are working on it and more of our customers are coming to us and saying that they want it.” With a successful demonstration already completed, and more on the way, this interest can only be set to grow. n NEWSBASE

August 2017

August 2017

InnovOil

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DoE offers new funding for subsurface, leak detection tech

US government department looks for technologies and research projects to aid unconventional production, as well as offshore leak monitoring

A

S US unconventional production shows little sign of giving up the ground and market share it has achieved during the long, hard few years since prices receded, efficiency gains and research into new technology are maintaining their pace. The government is also fighting hard to ensure those efficiencies endure.

In late June, the US Department of Energy (DoE) announced it would make US$20 million of new funding available for cost-shared oil and gas research projects, with a focus on technology and research which can help increase recovery efficiency from unconventional oil and gas wells and prevent offshore spills and leaks.

“This oil and gas research funding opportunity underscores the Department’s commitment to developing all of the nation’s energy resources,” said Acting Assistant Secretary for Fossil Energy Doug Hollett. “Increased efficiency and reliability of preventative and recovery measures promote our energy security, and contribute to making the United States energy dominant.”

According to the DoE, projects are aimed at three areas: two focused on boosting the recovery of unconventional oil and gas resources, and one on helping prevent offshore oil and gas leaks.

Of the total funding available, US$15 million will be used to validate existing or developing technologies using field laboratories. For this topic, the DoE divides technologies into two camps: those that can aid existing unconventional resource (heavy oil, shale gas, tight gas or tight oil) plays under active development and production exceeding 50,000 boepd, and those for emerging unconventional resource plays where there is currently under 50,000 boepd of production.

Projects could include hydraulic

fracturing studies such as fracture development and propagation, fluid and proppant emplacement, reservoir response and stimulated rock volume, as well as research into understanding petrophysical, geological, and geochemical conditions of reservoir rock and seals.

New technologies to improve drainage volume and resource recovery efficiency are

of interest, as well as real-time, “ahead of the bit,” remote sensing technology and smart technologies – the DoE uses the examples of “smart” drilling mud and cement.

Deeper understanding A further US$ 3million will be made available for advancements in subsurface diagnostics.

The DoE notes that these two areas address critical gaps in the understanding of reservoir behaviour and optimal completion, stimulation and recovery strategies for NEWSBASE

unconventional oil and gas. This could include technologies or research projects aimed at digitised datasets for subsurface geology, permeability and faults; techniques that measure changes in subsurface stress magnitudes and/or directions during water injection activities, as well as tools and technologies, and methods to forecast, mitigate and manage the risk of induced seismicity.

Research may also be focused on new physics-based geomechanical models, new methods of processing existing geophysical data, as well as distributed temperature sensing (DTS) and distributed acoustic sensing (DAS) fibre optics, among other topics.

Meanwhile, US$2 million will be made available to investigate research and technology to help offshore oil and gas spill and leak prevention. Here, the aim is to aid the development of solutions that predict geological hazards, and prepare for and prevent offshore incidents through risk reduction and mitigation technologies.

Of interest, it says, are solutions for improving the mapping and modelling of sub-salt sediments (to help determine whether areas are more prone than others to overpressure and “especially those focused directly on reducing the risk of blow-outs in an active exploration area in the deepwater Gulf of Mexico.”

It also mentions technologies for well control, including geochemical sensors for monitoring in-situ fluids, as well as subsurface and subsea monitoring systems, processes to prevent hydrate formations and well integrity solutions.

All in all, the call for proposals opens up a wealth of territory for US innovators.

Those with potential solutions are advised to read the additional information available via the National Energy Technology Laboratory website. n

page 8

InnovOil

GE Oil & Gas completes merger with Baker Hughes

August 2017

After nine months of negotiation, the Baker Hughes-GE merger was finally completed on July 3

B

AKER Hughes is now officially a General Electric (GE) company.

US-based GE’s London-based GE Oil & Gas subsidiary officially merged with oilfield services giant Baker Hughes on July 03. The resulting provider of oil and gas services and equipment is the second largest in size in oilfield services after Schlumberger.

The new firm’s stock began trading on July 05. Baker Hughes had already ceased trading. The merger follows Halliburton’s unsuccessful attempt to purchase Baker Hughes in 2016, which failed because of anti-trust issues.

GE owns 62.5% of the new company, officially named Baker Hughes, a GE company (BHGE). The merged entity is also now describing itself as “the world’s first and only fullstream oil and gas company”. It is expected to tap into two of GE’s strengths – digital technology and “big data” – for the upstream, midstream and downstream sectors. That is, it will provide a broad range of equipment and services ranging from offerings for exploration and production to the refining and petrochemicals businesses.

BHGE has headquarters in both Houston and London. GE Oil & Gas’ CEO, Lorenzo Simonelli, has moved on to become the new BHGE CEO, while the former Baker Hughes CEO, Martin Craighead, has become BHGE’s vice chairman.

The tie-up was agreed in October 2016 and approved by the US Department of Justice (DoJ) in June. European Union regulators approved the merger in May. And 99% of shareholders of both companies voted in favour of the deal on June 30.

In a press release, Simonelli said: “Disruptive change is the oil and gas industry’s new normal. We created BHGE because oil and gas customers need to withstand volatility, work smarter and

bring energy to more people. Our offering is further differentiated from any other in the industry across the value stream and enables and assists our customers in driving productivity, while minimising costs and risks.”

BHGE is expected to benefit from the longer-term rebound in oil and gas prices after the cratering of the market over the past few years, and the recent modest recovery. However, oil prices have started to wobble again, surprising the market forecasters and the US rig count is dropping, prompting concerns that tight oil production could start sliding once more.

According to the Financial Times, BHGE expects to achieve US$1.2 billion per year in cost savings by 2020 and to have “revenue synergies” of US$400 million per year by then. BHGE will have combined revenue of approximately US$23 billion, reported the newspaper.

Asked about oil producers’ apparent slow-down in the US market, Simonelli told Bloomberg in an interview on the eve of the finalised merger: “I think they need a little more time over the course of this year to make those decisions.” He was queried about the new company’s profits for 2018, given NEWSBASE

recent market uncertainty. “It’s a little early to say,” Simonelli responded.

BHGE has said that it will combine the physical and digital to increase reliability and uptime. “Applying digital and advanced technologies to oil and gas could bring approximately 5% productivity improvements across the entire industry,” the company said in a statement. “BHGE will use cloud-based software, advanced manufacturing and brilliant factory solutions to help its customers capture some of this opportunity – reducing risk and improving productivity in their operations as well as its own.”

Simonelli told Bloomberg that his priority was to reap synergies but retain the two companies’ market share. He can succeed, he said, because BHGE has the skills to outmanoeuvre its rivals.

“I think we’re number one,” said Simonelli. “When you look at the people we play against – a Schlumberger, a Halliburton, a Weatherford – they don’t have the same portfolio that we do.” However, like other oilfield services providers, BHGE will need to weather the storm of uncertain crude prices and a risk of declining oilfield service revenues. n

August 2017

InnovOil

page 9

Minox launches DryGas system Minox Technology provides cost-efficient gas dehydration with a smaller footprint

A

S operators look to make platforms and refineries smaller, leaner and more efficient, gas dehydration systems have been a key area of innovation in recent years. Typically, drying wet gas requires bulky and expensive steel dehydration towers which can be as high as 30 metres, weigh a great deal and take up valuable room, especially on a platform.

As a result, technology developers have sought to miniaturise these systems. In early January, for example, ExxonMobil licensed its cMIST technology to Sulzer. This dehydration system uses a droplet generator and proprietary in-line separator technology to reduce the footprint needed to dry produced gas.

Norway’s Minox Technology has also proposed a revolutionary approach to the issue, and following a successful large-scale testing operation, has launched its own patented technology. The Minox®DryGas system uses compact components alongside state-of-the-art static mixers and scrubbers, all of which are built into small compact modules to reduce overall size.

Minox, a process technology company based in Notodden, has previously marketed produced compact deoxygenation (deaeration) systems for oil and gas, used to treat water prior to injection into oil producing reservoirs.

The DryGas system uses two separators, each with a static mixer mounted upstream, in combination with triethylene glycol (TEG) for moisture extraction. This approach reduces the size and weight of the system by 50-70% compared with conventional drying towers, offering major benefits for space-sensitive offshore applications.

The system also requires less TEG in circulation than conventional contactor towers, in addition to a very low pressure drop. This too offers a reduction in size, weight and energy consumption of the TEG NEWSBASE

regeneration units, again helping to reduce both Capex and Opex.

Minox also says the system can play an enabling role in subsea gas dehydration – another key area of research for major technology backers, including ExxonMobil.

The recent trial was conducted in partnership with Statoil and the Norwegian Research Council, and supported by 5.3 million kroner (US$650,000) in funding from the latter’s Demo2000 programme.

Tests were undertaken at Statoil’s K-lab test centre, in Kårstø.

According to a June update from the company: “Test results were very convincing, and the Minox®DryGas technology was consequentially approved by Statoil to be ready for first commercial use.

The technology is obviously well suited for greenfield projects, but due to the system’s design and flexible installation methods, it is very well suited for the brownfield market including upgrades, extensions, [and] performance improvements.”

The DryGas system has approved patents in Norway, UK and Brazil. n Contact: Bjørn Einar Brath, CEO Minox Technology Tel: +47 35 11 57 00 Email: ber@minox.no Web: www.minox.no

InnovOil

page 10

On the radar

What caught our attention outside the world of oil and gas this month

Making WAVEs

Fixed-wing UAVs offer greater flight distance, but require sizable flat land to take off and touch down. But one solution proposed by the University of Sherbrooke in Canada is not to use land at all.

The team’s fixed-wing drone, dubbed SUWAVE (Sherbrooke University Water-Air VEhicle), is able to use bodies of water to take off and land, thanks to an ingenious solar battery system and a hinged propeller.

Weighing just over half a kilo, the ultralight drone is able to pivot its front

propeller. The heavier mass of electronics in the unit’s body pulls the rear of the craft down and its nose up, until it has enough thrust to take off – at which point the hinged propeller tilts forward, to fly like a conventional aircraft.

Landing is simply a case of finding another lake and bring the drone gently to the water, where it can then recharge via its wing-mounted solar panels.

The group intends to conduct further tests on the unit this summer. n

August 2017

The yeast you could do Contamination of the environment by heavy metals is often a serious consequence of major industrial activity. Cleaning up these pollutants is even more problematic, as many chemical extraction methods can cause even more serious damage, and poses risks to those undertaking the clean-up.

Using biological organisms to remediate these areas is one solution. We have already seen results in cleaning up oil spills offshore, but plants and other organisms may be deployed to soak up heavy metals. Recently a team of Romanian and Norwegian researchers also sought to use engineered yeasts.

Their efforts were described in a paper published in the Applied Microbiology and Biotechnology journal. Ordinary baker’s yeast was altered to include new proteins: a cell membrane anchor; a green fluorescent protein, and one of three types of metalbinding peptides. (The green glow was necessary for the researchers to verify the location of the proteins).

This altered yeast was then tested for its ability to adsorb a number of heavy metal contaminants. Those samples with a peptide made of aspartate and glutamate were best at adsorbing copper and manganese ions, cysteine peptides at adsorbing cadmium and silver ions, and histidine peptides at adsorbing cobalt and nickel ions.

Overall, the best-performing samples were able to remove about 80% of the respective metal ions.

This still leaves the problem of collecting the yeasts once they have taken on heavy metal-contaminated yeasts, but may aid clean-up in identifying which areas of a site to target. Researchers also intend to scale up the process for trial in a water treatment plant or a real contamination site. n

Doffing a supercap Engineers at the University of Washington (UW) believe they have devised a manufacturing method to make better supercapacitor electrodes, and make them faster. This was described in a paper authored by the team (led by UW assistant Professor of Materials Science and Engineering Peter Pauzauskie) and published on

July 17 in Nature Microsystems and Nanoengineering.

The method uses carbonrich materials that have been dried into an aerogel, which offers a 3D structure with a high surface area and extremely low density. This material on its own can act as a crude electrode, but Pauzauskie’s team managed to more than

double its capacitance, which is its ability to store electric charge. “One gram of aerogel contains about as much surface area as one football field,” he noted. This material, coupled with a streamlined synthesis process, goes some way towards meeting two common barriers to industrial application: cost and speed.

NEWSBASE

The team believes that this advance may aid other energy technologies. Aerogelsuspended molybdenum disulphide may remain sufficiently stable to catalyse hydrogen production, for example, while the aerogel production method could also be applied to high-capacitance batteries or catalysis. n

InnovOil

August 2017

page 11

Seeing the zeolite Converting organic waste products into hydrocarbon fuels has been one of the main focuses of new energy research.

In many cases, however, the additional energy required for conversion renders these technologies uneconomic. One potential breakthrough may have arrived in the form of new research from the Technical University of Munich (TUM).

Using new catalysts, the team has been able to reduce the temperature and energy requirements of one step in the process significantly.

Central to the method is the use of zeolite crystals to catalyse the splitting of carbon-oxygen bonds. Confining the reactions to small spaces in these crystals in an acidic aqueous solution allows the splitting to take place at drastically lower temperatures, and also speeds up the splitting process considerably.

The team compared the reactions of carbon compounds with acids in a beaker to the same reactions in zeolites.

In the crystal cavities, where the reacting molecules, for example alcohols, meet upon the hydronium ions of the acids, reactions ran up to 100 times faster and at temperatures just over 100°C. This is reportedly the result of the

porous structure of the zeolites, which provide greater surface area on which reactions can occur. When they come into contact with hydronium ions, organic molecules such as alcohols lose oxygen.

Hydronium ions within the cavities have a significantly greater likelihood of bumping into a reaction partner than those outside, meaning an acid-catalysed chemical

reaction will take place faster and with lower energy input.

The system is not yet commercial, and Lercher and his team are still pursuing more fundamental research. However, they are optimistic that the process could open up new opportunities for surplus renewable energy to be turned into fuels and fertilisers. n

Under the surface Researchers at the École polytechnique fédérale de Lausanne (EPFL) are bringing us closer to chemistry than ever before. Using a newly developed optical imaging tool, they can view surface chemistry in real time.

EPFL’s Laboratory for Fundamental BioPhotonics (LBP) has designed a microscope that can track, in real time, three-dimensional spatial changes in the molecular structure and chemistry of confined systems, such as curved surfaces and pores. The microscope was used successfully to image the surface chemical structure of the inside of a glass microcapillary.

The system may help better understand geological, catalytic, biological and chemical processes.

Surface potential maps were constructed from the millisecond images, and the chemical reaction constant of each 188nmwide pixel was determined. Surprisingly, this very simple system – which is used in many devices – displayed a remarkable spread in surface heterogeneity.

Sylvie Roke, director of the Julia Jacobi Chair of Photomedicine at EPFL explained that the technique uses second-harmonic and sum-frequency generation, optical processes in which two photons of a certain colour are converted into a new colour.

“The second-harmonic process involves 1,000 nm femtosecond photons – that is, 0.00000000000001-second bursts of light – being converted into 500 nm photons, and this occurs only at interfaces,” says Roke. “It is therefore ideal for interfacial microscopy.

Unfortunately, the process is very inefficient.

NEWSBASE

But by using a number of optical tricks, such as wide field imaging and light shaping, we were able to enhance both the imaging throughput and the resolution, bringing the time to record an image down from minutes to 250 milliseconds.”

Data from these images will aid the development of theoretical models that are more effective at capturing the complexity of the interface between silica capillaries and water, as well as offering insight into nanochannels and both artificial and natural pores. n

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ROVs and UAVs

page 13

SPECIAL SUPPLEMENT Pages13-27

MULTI-TASKING The JFSE MultiROV Page 17

THE X FACTOR

SkyX’s VTOL UAV Page 19

MODULAR MORPHING

DTU’s autonomous ROV programme Page 20

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InnovOil

page 14

Super collider

August 2017

ROVs AND UAVs

Flyability’s collision-resistant Elios drone is the next step in safer remote inspections

I

N just a few short years, unmanned aerial vehicles (UAVs), or drones, have revolutionised inspection techniques.

Having conquered outdoor and offshore infrastructure environments, they are now well-proven as a method of inspecting large internal structures such as silos, onshore storage tanks and vessel ballast tanks. Where next, then?

The answer, it would seem, lies in making them safer, more capable and easier to operate. The potential for drone to collide with the environments around them still represents a significant danger to infrastructure and to the equipment itself.

In working to prevent this, the hope is that these vehicles may be deployed safely in ever-more hazardous environments, and further reduce the need for human access.

One company leading the charge is Flyability. Founded in Lausanne, Switzerland in 2014, the drone designer and manufacturer is a spin-off of the country’s prestigious École Polytechnique Fédérale de Lausanne (EPFL). Headed up by engineers and co-founders Dr Adrien Briod and Patrick Thévoz, it has won numerous awards and accolades for its remarkable Elios UAV, billed as the world’s “first collision-tolerant drone.”

The innovation was partly inspired by the need for accurate inspection tools during the assessment of damage to the Fukushima nuclear plant in Japan, in 2011. Watching reports of the site on the news, Briod saw the difficulties faced by ground-based robots attempting to navigate debris, and by aerial vehicles operating in confined spaces outside of operator’s line of sight, and dedicated his academic research to finding a way around it.

Housed in a flexible frame, the vehicle that resulted from this research is designed to enable inspection and exploration of the most inaccessible enclosed places, the company says, allowing drones to work in complex, cluttered or indoor spaces that were previously off limits.

Bouncing off the walls Our attention should first turn to Elios’ defining feature: the unusual cage-like frame on the outside of the drone.

Designed by Flyability, the patented spherical frame is made of carbon fibre “pentagons” covered with a soft coating.

This helps to trim weight – the frame is around one third of the total system weight – while the materials used allow it to sustain collisions at any point in the frame, at speeds of up to 5 m/s (18km/h), without affecting flight or performance; Elios simply bounces and rolls along its path.

Like many innovations, Briod took Inspiration from the animal kingdom – or more specifically from insects. Flyability marketing manager Marc Gandillon elaborated: “Insects are very efficient at NEWSBASE

sensing and avoiding obstacles, but also being tolerant to them – think of a fly hitting a glass window and recovering. Briod’s research looked to reproduce this behaviour in a drone.”

This is achieved thanks to some clever engineering on the mounting. If a frame was fixed around the drone, any collision would roll the vehicle, push it upside down, and prompt a crash. Instead, the drone itself is decoupled along three axes, using a gimbal mechanism, allowing it to remain stable

August 2017

InnovOil

page 15

ROVs AND UAVs

Elios inside a coal-fired boiler superheater

even in the event of a collision with a structure (or human).

“Decoupling of the frame is the uniqueness of this drone,” Gandillion added. “When you have a collision this absorbs the force and a control algorithm that handles the stability of the drone will compensate for the shock, so the whole system will remain stable.”

Its overall diameter is just below 400 mm.

This is another purposeful decision, as it renders the whole system slightly smaller than the smallest standard manhole – again enabling maximum possible access to potential inspection environments. Inside, modular components including the battery and SD data card are accessible by hand through the open frame.

To those familiar with drone inspection, Elios’ payload will look very much as

standard, albeit with some high-end additions. Its primary equipment is an HD camera mounted on a rotatable head. This captures images above and below with a vertical field of view of 215° and a horizontal field of view of 130°. This offers a resolution of 1920 x 1080 at 30 frames per second, with adequate image quality even in low light.

When brought into contact with a surface, the system can collect close-up images to a resolution of 0.2 mm/px, with remotely adjustable exposure.

Simultaneously, the system also captures images from a separate thermal camera, in slightly reduced fields of 42° vertical and 56° horizontal. This system can aid leak and crack detection, as well as improving visibility for the operator in environments with very little light. For the rest of the time, the five arrays of LEDs should provide sufficient illumination to the in front, above and below the robot.

The battery offers enough power for around 10 minutes of flight and inspection on a single charge. This might not seem like a great deal, but given the planned nature of inspection missions, and the fact that Elios is designed for indoor use, rather than highaltitude flying, the swappable packs should provide more than enough flexibility for most applications.

Insight without line of sight Imaging feeds are logged to an on-board SD card, as well as being streamed directly NEWSBASE

to the pilot at a lower resolution, via a 2.4Ghz comms link. This bandwidth itself offers users a distinct advantage; as well as preserving a high quality of data transfer, this system does not require any special authorisation to operate.

The strength of bidirectional signal between the Ground Station and the drone itself also allows for long-range travel, even when working beyond line of sight (BLOS).

Based on DJI’s Lightbridge 2 broadcasting technology, Flyability says Elios is capable of maintaining signal at 150m altitude, or 150m of tunnel with minor curves. In more enclosed environments, Elios should be able to work inside of tanks, or throughout several floors of building, while the operator pilots from outside. (It is also worth noting here that unlike flying drones outside, few governments have introduced legislation to regulate indoor drone flight, meaning Elios users should be able to carry out inspections without seeking additional permitting).

Using the Ground Station, the pilot has access to live telemetry data including, among other things, battery, heading, altitude and flight time.

In May 2017, Flyability also introduced a range extender module, with a view to increasing the usable range of the vehicle in difficult environments, such as underground tunnels or a mine. The 20m extension line works as an accessory to the Ground Station, enabling an antenna to be placed in a more suitable location for the mission.

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Elios used in a refinery radiant box inspection For example, an operator can lower the unit from the surface into a 20m manhole, offering Elios better communication and longer range when inspecting the tunnel.

This also allows the operator to remain at a safe distance from any potentially hazardous sites, without compromising the quality of data. The drone, meanwhile, will always fly within range of signal – limiting the possibility of recovery issues.

Applications InnovOil has already reported on the use of quadcopter drones in enclosed marine and oil and gas industry environments, but it is fair to say the added collision-protection offered by the Elios system is a highly valuable proposition for asset owners and inspection service providers alike. Although Elios systems are sold directly to customers – Flyability has “no plans” to become an inspection services provider itself – Gandillon noted that: “Inspection of storage tanks is the strongest use case we have in oil and gas.”

Typical tank inspections – whether onshore or offshore – require the unit to be drained, cleaned and ventilated before scaffolding is installed and/or rope access technicians can begin IMR work. Because drones are not inherently safe for use in

ATEX zones, the first steps have to be performed anyway. However, an Elios system can then be dispatched to survey inspect the tank walls prior to scaffolding and technician work, allowing asset owners to plan a far more time- and cost-efficient operation, and scaffolding only the areas which require maintenance. “What our value proposition is that you want to know where you have to do repairs before you start planning resources… If you know before you start scaffolding where you have to do repairs, it is much more cost-efficient,” Gandillon added.

Elios drones have been used for many inspections including refineries, chemical and hydrocarbon storage tanks and marine ballast tanks. In one case, two 15m by 12m ballast tanks on CMA CGM’s Andromeda vessel were inspected during six 10-minute flights, a during job which lasted just two hours from deployment to completion.

Moreover, the pilots operated the drone from above the tanks, without entering the structure at all – representing considerable safety and time improvements.

The company has its eyes on future capabilities too. According to Gandillon, ongoing R&D is focused on automation, ease of use, data quality, and flight time. Automation will help when doing NEWSBASE

very systematic inspections. Improving operations in GPS-denied environments (where stabilising the system can be very difficult) is necessary to make the tool accessible to those who are not drone born a drone operator. Seeking for an always better data quality but also different type of data (i.e. 3D mapping) will help serving a larger range of customers. With the automation of flights, an extended battery life will start to be necessary. “All the research that has happened with outdoor technology, we definitely have the same indoors, it’s just that the constraints are different and the technology is maybe 5-10 years behind, for now,” he explained.

Nevertheless, the added safety benefits of a collision-tolerant vehicle such as Elios raise a number of intriguing possibilities across the industry. “Any environment where space is tight, indoors and difficult to access or highly regulated, then our drones start to be interesting and useful,” Gandillon remarked.

With no shortage of such places in oil and gas, Flyability has plenty of interest to keep Elios rolling along its way. n Contact: Flyability

Tel: +41 21 311 55 00 Email: sales@flyability.com Web: www.flyability.com

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The subsea multi-tool

JFSE has designed the MultiROV, the first dedicated mass flow excavation package for the deepwater market

W

ITH efficiency and cost reduction driving most of the innovation in the industry, multipurpose tools are gaining more traction. In many cases, the ability to take on multiple jobs has also allowed many subsea firms to take on work in sectors other than oil and gas – offshore wind farm development being a particular target in the North Sea. InnovOil has already covered innovations from the likes of Utility ROV Services, and many operators are looking to benefit from the ability to complete multiple aspects of a project using a single vessel.

The latest such equipment comes from James Fisher Subsea Excavation, a unit of marine engineering firm James Fisher and Sons. Formed in 2014 following the combination of KDM Marine and James Fisher’s own mass flow excavation (MFE) business, the company provides a fleet of tools for non-contact subsea excavation.

This form of subsea excavation, also including controlled flow excavation (CFE), is preferable around sensitive or complex assets, and allows operations such as pipeline and cable trenching, de-burial, rock dump dispersal and seabed clearance to be undertaken with reduced risk to the asset.

M/CFE spreads are ideal for moving materials such as sand, silt and mud, drill cuttings, clay and rock dump.

Its latest innovation, dubbed the MultiROV, is designed to operate a number of different tools during one deployment, increasing the efficiency with which operators can undertake inspection, repair and maintenance (IRM) campaigns.

“The initial design criteria was to develop a system where the proven mass/controlled flow excavation technique could be utilised in the deepwater market,” JFSE technical director Graham explained to InnovOil via email. “We had attempted this a few years ago by hiring an electro-hydraulic power pack and mating our patented excavator to this. Although the concept was solid, we encountered challenges with the design. We decided to design and build our own system, as we were confident there was a market for our expertise in deepwater projects due to enquiries from potential clients.”

Thrust-have Developed in partnership with ROV specialist Aleron Subsea, the MultiROV reduces the services required from a vessel, because it requires no stabilising tuggers or clump weights. Instead, on-board thrusters enable movement and heading control of the tool and allow for the accurate positioning of subsea tools directly over the target area. This means engineers can get to work on undertaking more jobs, with less time waiting around.

Weighing 2.5 tonnes and needing a volume of just over 2 cubic metres, it is deployed via 20 tonne SWL lift frame with hydraulic locking ram. Four 380-mm hydraulic thrusters provide up to 300 HP of excavation power, with a maximum flow of 600 litres per minute, and maximum pressure of 300 bar.

In low light conditions, 4 LED lights provide illumination.

“Any vessel with a crane or A-frame would be suitable for deploying the seven tonne MultiROV. One of the main benefits of utilising this system is it reduces the demand on the vessel,” Murdoch added.

Versatility is also important. Because it does not require stabilising infrastructure, it can be used at any depth over 4 metres, down to 3,000m and below. In that regard, the company says, it the first fully dedicated M/ CFE tool for the deepwater market.

The MultiROV then provides a platform to operate additional subsea tooling, such as grabs, shears and suction dredgers, again without the need for separate tool deployment.

Autoheading and depth feedback come as standard, meaning the system will maintain its NEWSBASE

own position, but the system boasts additional data-hosting capabilities, allowing it to run a multitude of useful subsea survey sensors, including cameras and multi-beam sonars.

This enables added flexibility in terms of realtime data capturing during operations, and helps operators better assess the condition and layout of their assets and the seabed.

In a separate statement, Murdoch commented: “This is an exciting advancement in excavation technology. The MultiROV will bring real benefits to our clients with a range of challenging requirements. Automated heading and positioning controls greatly increase both productivity and the operational working limits.”

In total, JFSE offers a range of 30 equipment spreads, all of which are capable of real-time sonar imaging. This enables precision excavation in confined areas, as well as for all cable or pipeline trenching works with diameters from 1” to more than 60” scopes (25-1,524mm). As well as deepwater operations, JFSE believes the system will offer major benefits to its work in the decommissioning and offshore wind farm markets.

JFSE works from a number of hubs in the UK, UAE, Singapore, Venezuela, USA, Brazil, China and Mexico. As such, it believes it is the only M/CFE contractor capable of working on multiple projects simultaneously. The MultiROV will no doubt play a central role in enabling this further. n Contact: JFSE

Email: enquiries@jf-se.com Web: www.jfsubseaexcavation.com/

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SkyX pushes the limit

Canada’s SkyX is using a proprietary VTOL UAV to inspect pipelines

I

T is not a quadcopter, and it’s not quite a fixed-wing UAV – so what is it?

Drone inspections tend to fall into two camps: shorter dedicated inspection missions are flown using small quadcopters, or longer-range monitoring and mapping missions performed by larger, fixed-wing UAVs. For major long-term projects, the latter is of course the preferable choice, but such UAVs require a suitable runway or launching infrastructure, transport and a fair amount of human oversight.

Ontario-based SkyX has a different solution, instead using a pioneering design that combines the vertical take-off and landing (VTOL) capabilities of a quadcopter with the endurance of a fixed-wing UAV. In combination with an innovative charging station and monitoring software, the company claims that its suite of systems, dubbed the SkyX Solution, offers the energy industry “the most sophisticated and integrated long-range infrastructure monitoring platform available.”

Central to the platform is the SkyOne drone itself. The battery-powered aircraft is capable of travelling around 65 miles (105 km) on a single charge, and thanks to its four-propeller VTOL system can take off from just about anywhere. It can be equipped with a range of imaging technologies, from basic visual image capture to thermal, infrared, LIDAR and other multispectral data, providing an in-depth data feed from an energy asset.

Moreover, it does so autonomously, meaning no human input is required.

The electronic components are

weather-sealed, allowing the drone to fly in conditions that may otherwise prohibit conventional UAVs. At present, SkyOne transmits all captured image data once it had landed, although future modifications may see this change.

The company confirmed to InnovOil via email that: “We are actively pursuing real-time image transmission in areas where there are existing cellular networks.

However, many of the locations where the SkyX System will be deployed are rural, and with limited connectivity.”

Most recently, SkyX has added an additional piece of infrastructure to its offering. Ground-based recharging and launching hubs, dubbed xStations, provide the SkyOne with a dedicated point to land, cache data and check its system functions – as well as extending potential mission range indefinitely. When not in use, these hubs are also enclosed, protecting the system from the elements. They can also provide waypoint for landing and data storage along longer routes. They are powered by a conventional electric outlet, but can also be plugged directly into generators, or on-site power infrastructure.

In the pipeline Pipeline monitoring operations in particular are where the start-up sees the greatest benefit for the system. Operators using the SkyX Solution would establish a network of xStations and drone flightpaths along set points in their infrastructure, enabling constant surveillance of the pipeline. This is then monitored by an autonomous fleet NEWSBASE

management programme, allowing the system to detect and report leaks – even at night – or to capture and report vegetation growth. Asset owners can also amend flight plans manually, or programme in additional inspections or tasks.

Should any leak or integrity issues be detected whilst a unit is surveying, a message is sent to the operator. In the event of an emergency, SkyOne drones can also be immediately dispatched to survey specific points of interest, enabling a rapid response.

While oil and gas assets are seen as the company’s first targets, it also sees potential in other infrastructure monitoring operations such as railway lines, coastlines and electrical grids. SkyX intends to market the system on a monthly subscription basis, which should help to reduce capex costs compared with other potential monitoring options.

The SkyX system is not currently available worldwide, although the company has seen interest from several countries.

“From a technology perspective, it can work worldwide,” SkyX head of media and communications Scott Simmie explained.

“It’s really more a question of regulatory frameworks in specific countries.”

For now though, Simmie says the company is in discussion with “several large companies on an international scale” and hopes to be able to reveal more within the next few months. n Contact:SkyX

Email: contact@skyx.com Web: skyx.com

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Getting REMORA from subsea robotics A team at Denmark’s DTU is designing a new kind of modular, subsea-resident autonomous robot.

Andrew Dykes speaks with one of its architects

R

OVS may be one of the offshore industry’s most ubiquitous tools, but that does not mean they are the easiest to use. Operators require considerable skill just to perform what may be considered “simple” tasks – e.g. tightening a valve or bolt on a subsea manifold. Even many smaller models demand the patience, skill and practice that comes from an experienced ROV service provider.

But as ROV manufacturers look to new markets, in oil and gas and beyond, many businesses wish to perform their own regular inspections with small, affordable and versatile vehicles. Others would prefer to harness the power of autonomous systems to minimise human intervention altogether.

As such, there is a need to push new designs and tools to offer easier operation and greater capabilities.

In response, the Technical University of Denmark (DTU) has opened a laboratory where researchers will design a new kind of modular underwater robot. Central to its creation is the idea that the system should be accessible to a multitude of end-users.

“We have a vision of creating a modular robot that is simple to operate—without the need for technical experts. Initially, it will be able to inspect and monitor, for example,

the condition of the foundation of a wind turbine under water—or an ocean fish farming plant,” DTU Electrical Engineering associate professor Roberto Galeazzi explained.

Dubbed REMORA – REconfigurable MOdular Robotic system for Aquatic environments – the underwater robot will be designed for inspection, maintenance and repair (IMR) of marine structures and environments in confined waters, i.e. the surroundings of larger offshore and subsea infrastructure. But DTU has even grander plans for the modular system.

“In the long term, the intention is for the modular robot—which comprises several independent robots (modules) that can both work coupled together and individually—to also carry out repairs on the foundation,” Galeazzi said.

Lessons from Siri The original impetus for development came in 2013 when Galeazzi and his colleagues David Johan Christensen, Jens Christian Andersen and Mogens Blanke were approached by a subsea technology consultant working for the oil and gas sector to discuss some of the challenges related to the use of large work-class ROVs for subsea inspection of oil and gas platforms. This NEWSBASE

was spurred during the shutdown of DONG Energy’s Siri platform due to the presence of cracks in several areas of the project’s subsea tank – a failure which resulted in considerable lost production time.

“The major challenges put forward were that current ROV technology was unfit to navigate and operate in narrow spaces like those in focus during the repair of the Siri platform, and the lack of robotic technology that could be utilized to e.g. inspect the subsea tanks from the inside,” Galeazzi told InnovOil by email. “In these challenges we identified an opportunity for disruptive innovation.”

The group outlined parameters which would become the future blueprint for REMORA: that ROVs would have to be autonomous, modular, fault-tolerant, multiagent (including models for swimming, walking, crawling) and collaborative if they were to truly revolutionise resident subsea IMR. That vision supported two PhD projects in 2014, overseen by Blanke and Christensen, and with further development and private funding in 2015 from the Danish Orients Fond, the REMORA lab was established in February 2016.

Overseen by the DTU Maritime centre, the project involves some of Denmark’s most talented robot researchers, and work

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Two ROVs approaching robot-to-robot docking

in the laboratory includes developing both hardware and software to manage a modular system. Currently the laboratory is equipped with 8 ROV platforms produced by Blue Robotics, and each REMORA unit has a standard package for navigation, including an IMU (3-axis accelerometers, 3-axis gyroscopes and 3-axis magnetometer) and a depth sensor – this is the minimum payload that would be integrated into each module.

Over the past 18 months or so, many students in the REMORA lab have already completed their first prototypes.

“The core idea of the modular system is the creation of robots that can dynamically change their morphology by interconnecting with other robots or tools (sensors and actuators) necessary for carrying out a specific task in an IM mission… Working in unison, the robots can draw on each other’s functions, thereby becoming fully autonomous,” Galeazzi said. “For example, thruster failure in a swimming robot will no longer represent a reason to abort a mission, since a fellow agent could swim in, connect with the failing agent and continue the mission together.” The same technique can be applied to other components or missions, to also improve battery performance, for example.

The intention is also for the REMORA

system to be subsea resident, using a permanently installed docking station for battery recharging, data transfer and selfrepair. The modular robot could therefore install and replace sensors from a subsea docking station placed on the foundations of a wind turbine or drilling platform, providing continuous monitoring.

Achieving this requires substantial engineering work, from software control systems to tools, in order to support a suite of ROV modules that are essentially plugand-play. Yet the researchers are confident that, when fully developed, these will allow for greater adaptation of robots to individual missions or tasks. In turn, that should help increase resiliency to faults and failures, and will allow better endurance and longer-term autonomous operations.

Modular morphology The concept combines a few of the ideas that have been floating around the world of subsea robotics. Last year, InnovOil reported on the subCULTron research project, which sought to design and build swarms of autonomous robots that could interact and communicate. Meanwhile, most commercial new robotics ventures – Eelume, for example – are already looking at some degree of modularity in their payload assemblies, NEWSBASE

allowing operators to specify the equipment needed for missions. Few, however, have sought to combine all these disparate elements.

Over the past year, the team has achieved much in the way of early-stage development.

In addition to setting up the laboratory and the third-party ROV test systems, the group has successfully designed, manufactured and tested the first prototype of the so-called intelligent robotic reconfiguration module (iR2M). This is the black device mounted in front of the robots (visible in the pictures above), which enables ROV interconnection and docking.

According to Galeazzi, further work on the iR2M will enable the possibility of expanding new ROV payloads. He pointed to collaborative work with the SENTINEL project at DTU Aqua, a cognitive robotic system for underwater monitoring and sampling, which aims to upgrading the robotic payload with a sensor module for measuring spectral fluorescence. Another tie-up with the Underwater Time Of Flight Image Acquisition (UTOFIA) project would see a module host a newly developed timeof-flight vision system.

Naturally, other engineering challenges lie ahead. DTU’s ROVs must withstand the demands of their working environment,

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ROVsROVs AND UAVs

An ROV attached to a docking module on a static structure

including marine fouling, strong currents and potentially poor communication signals.

Yet at the same time, the units need to remain small enough that the overall system does not become bulky and difficult to manoeuvre, Galeazzi said.

The team must also continue to engineer a connection mechanism – the iR2M – capable of supporting all its planned modules. “To minimise complexity and maximise flexibility, we would like to develop modules that have a universal interconnection mechanism –both mechanically and electronically. This will enable the robot to change its morphology in a completely arbitrary way without being limited by the fact that it can connect only to certain components, due to its own connectivity layout,” he continued.

Swimming unaided DTU also has its eyes on the advances in robotic autonomy over the next 5-10 years. The team has already developed its own vision-based motion tracking system which supports autonomous swimming in a laboratory environment, and currently allows the closed-loop control of a single agent. “After the summer we will upgrade our vision system to a camera with high frame rate so that we will be able to track

and control multiple agents at the same time,” Galeazzi added. This system is used in the test tank, but future sea trials will require equipping the robots with an acoustic or optical localisation system, he said.

From there, the lab will follow two distinct lines of development: the first will focus on developing the systems for modularity, while the second will lay the groundwork for a subsea communication system. “Plenty of work will be allocated to the reinforcing and testing of the robotic reconfiguration module, and also to the design of a so-called sensor module,” he continued. “On one hand this will allow the robotic system to dynamically change its sensing payload, and on the other hand allow it the creation of a deployable sensor network to monitor things like the structural integrity of wind turbine foundations or oil rig jack-up structure.”

The communication system too poses difficulties, since it is the key to creating a multi-agent system that can collaborate by sharing information while in operation.

However, he is confident that improvements in optical communications – increasingly miniaturised equipment in conjunction with the ability to achieve higher bitrate transmission – will enable an autonomous multi-agent subsea network to be realised NEWSBASE

– and perhaps even sooner than the marine industry thinks.

All of which open opportunities for further industry involvement. Given the scale of REMORA’s ambition, further collaboration will be essential to realising the technology’s full potential. “I believe that the best way to purposefully innovate is to team up with industrial players that have been active in the offshore industry for decades, since they have the know-how about the limits of current technology and the challenges faced in IMR operations,” Galeazzi remarked.

The sheer scale of opportunity for modular, resident subsea solutions like REMORA means the race for development is already on. Yet Galeazzi and his team believe that their awareness of the particular demands of the offshore industry will enable their technology succeed: “We would like to shape our innovation and development around concrete issues, so that the new technology we bring to the table has a true impact on the offshore industry.”

If REMORA can deliver on its potential, we foresee a substantial impact indeed. n Contact: Roberto Galeazzi

Tel: +45 4525 35 49 Email: rg@elektro.dtu.dk Web: www.elektro.dtu.dk/

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OGIC backs emergent robotics Collaborative projects with emergent technology developers and leading universities are already producing results

W

ITH new technologies bringing the promise of increased benefits and solutions for the oil and gas sector, the UK’s Oil and Gas Innovation Centre (OGIC) is looking to increase investment in emerging technologies and encourage more open collaboration across the sector.

Remotely operated vehicles (ROVs) have been used in the offshore sector for some time. However, advancements in autonomous robotics technology that improve its ability to learn, adapt and make decisions independent of human control, are providing enhanced solutions and benefits for subsea operations.

A recent McKinsey study into disruptive technologies estimates that by 2025 RAS technologies will have a total impact on the global markets of between US$1.9 and US$6.4 trillion per annum. The report also highlighted the potential competitive advantage of such technologies for early adopters, who could gain quality, cost and speed advantages over competitors.

Innovate UK believes there is great potential for new applications and opportunities to grow as technical capabilities extend and the energy sector gains an increased understanding of the potential gains. With advanced Robotics and Autonomous Systems (RAS) helping to reduce health and safety risks, provide cost efficiencies and create new exploration opportunities, there is now a growing trend within the subsea sector to move towards greater utilisation of this technology, in particular autonomous vehicles.

Trends in “swarming” robots that can work together alongside humans and quickly sense and react to their environment, have the potential to revolutionise search and rescue operations, as well as performing operational tasks more efficiently in hazardous deepwater environments.

“Underwater swarming robots make use of many Autonomous Underwater Vehicles (AUVs) working together collaboratively.

This collaboration allows robots with different capabilities to work together making best use of the sensing and actuation resources that are available. For example,

WBS used on field trials in the Mediterranean

an AUV with a particular capability can come in to inspect a specific area of interest whilst the other robots continue with their survey. The different robots can feed their findings back separately whilst they have been working in parallel speeding up the overall survey or inspection task,” explained Dr Keith Brown, associate professor in the Oceans Systems Laboratory at Heriot-Watt University.

By making the AUVs smaller, without requiring all of the sensors on all of the vehicles, the overall costs will be lower and one vehicle failing does not necessarily cause the end of the mission. The benefit of enabling companies to inspect and assess the integrity of subsea infrastructures in safer and more effective ways is also of increasing interest to the renewable energy sector, as well as the decommissioning industry.

RAS to be first To ensure that companies within the oil and gas sector and the wider energy industry have every opportunity to access RAS technologies, OGIC is identifying and investing in research and development (R&D) projects in this emerging field. By connecting oil and gas companies with relevant academic expertise in Scottish NEWSBASE

universities, as well as providing part funding for viable projects, OGIC is helping to ensure that real industry problems can be explored and resolved using cutting-edge technologies.

A recent project facilitated by OGIC in this area involved an R&D partnership between Heriot-Watt University’s Ocean Systems Lab (OSL) and the sonar and underwater systems company, Hydrason Solutions. Together the pair worked on the development of a specialist system to improve the maintenance and repair operations of subsea structures, specifically pipelines and power cables.

Applying its extensive knowledge in underwater sensing technologies, OSL was able to make a significant advance in improving low frequency (LF) sonar technology for offshore oil and gas survey work. This has the potential to provide enhanced information for key challenges in flow assurance, condition-based maintenance and integrity management.

The development of new sensors, such as the wideband sonar, provides new information through intelligent application of bio-inspired sensing and processing. Accessing the quality of information in the harsh subsea environments will improve the sensing and operational capabilities of the new generations

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ROVs AND UAVs Deploying the WBS (Wideband Sonar System) on the REMUS-100 vehicle in recent field trials in Weymouth, UK. Picture: Hydrason Solutions

of subsea robots currently being developed for use in the offshore energy sector.

OGIC chief executive Ian Philips commented on the recent collaboration between Heriot-Watt University and Hydrason: “Collaborations, such as that of Heriot-Watt University and Hydrason Solutions, have the potential to bring further cost efficiencies for the sector. However, more importantly, collaborations also enable increased access to expertise to find innovative solutions and improved processes for current industry challenges.

“We are seeing real benefits of such collaborations with the projects we are facilitating for the sector, and we are keen to increase the number of projects OGIC is doing with emerging technologies – especially in robotics and autonomous systems, which is generating a lot of interest in the sector right now.”

By facilitating access to R&D facilities, such as the OSL at Heriot-Watt University, and supporting projects with part funding, companies are getting the opportunity to do more feasibility studies and accelerate concepts to the development stage, where prototypes and field-testing can be explored.

Chris Capus, CEO of Hydrason Solutions, said: “For Hydrason, the collaborative

project sponsored by OGIC has pushed development of our sensors towards lower frequencies, which are required for oil and gas infrastructure. We were pleased with the progress made whilst working with the team at Heriot-Watt University. Continuing this development, our current focus is to extend the operating depth for our systems to 3000m to meet the mounting challenges of deepwater oil and gas exploitation.

“Together these advancements will provide new sensing capabilities for preand post-installation surveys looking into the sub-bottom sediments and for a greater range of subsea structures for the oil and gas and renewables energy sector.”

Dr Brown emphasised the need for investment and collaboration across the energy industry: “We are working to increase the use of autonomous vehicles in the offshore energy sector, as it will help the wider industry, the environment and ultimately the consumer in several ways.

The project from OGIC has helped us to work with Hydrason Solutions to create a specialist system to be used for analysis and to tackle issues with assessing the condition of subsea assets. The project has been valuable in bringing our organisations together to determine what is achievable.”

NEWSBASE

Active engagement With emerging technologies providing faster and more efficient solutions for industry challenges, it is vital that the sector does not ignore the potential value of investing in niche markets such as robotics and autonomous systems. This technology can provide new opportunities for deepwater exploration and improved processes that are not only safer and faster, but also more cost effective to deploy.

Within Scottish universities, there is a wealth of expertise and facilities dedicated to advancing new technologies and innovative solutions for the sector. However, the greater challenge may not be finding the investment, but changing the mindset of the industry to share knowledge and be more open to the benefits of shared resources through collaborative projects.

With the objective of driving innovation in the sector, OGIC continues to engage actively with those companies that see the benefit of investing in these important niche market technologies. A continued investment and collaboration in these projects is not only critical to the future of the sector, but also vitally important to maintain Scotland’s lead in innovative technologies for the oil and gas sector – both in the UK and globally. n

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ROV operators soon to feel Blu New agreement between J2 Subsea and Seattle’s BluHaptics will see haptic controls and modelling support the use of ROV tools

F

OR all the advantages that ROVs can offer subsea operations, actually learning to manoeuvre them is a tricky business. The disconnection – and occasionally grainy communication – between a topside operating console and the vehicle itself can certainly make piloting a challenge. To address this, haptic and augmented technologies can provide additional feedback, and bring pilots closer to the action.

BluHaptics is a Seattle-based software company developing new technology to aid augmented robotics. In June the company formed a partnership with subsea tooling and services supplier J2 Subsea, which will see its augmentation software sold alongside J2’s existing product and service portfolio, with a view to helping make the operation of underwater manipulator arms safer and more effective.

Using haptic guidance control, machine learning and data fusion, the company aims to simplify robotic operation in real time.

BluHaptics has integrated a number of

technologies, including real-time modelling, operator assistance, and force feedback, into one platform for semi-automatic robotic control. This features a virtual interface and more user-friendly controls, making it significantly easier for operators to control remote robots more precisely when subsea.

Having typically focused on the rental, service and repair of subsea tooling hardware, J2 Subsea is incorporating BluHaptics software into its suite of offerings to provide all its customers with a greater level of control and precision. “We are looking forward to offering BluHaptics’ software. This is a leap forward in robotic control for an ROV industry standard tool,” said J2 Subsea director John Walker. “The software will enable increased precision, reducing the instances and intensity of damage to ROV manipulator arms during subsea operations.”

Several offshore trials of the system are now currently under way, and a full release of BluHaptics’ new application for NEWSBASE

underwater manipulator arms is scheduled for later this year.

“Augmented robotics marries the strengths of humans and robots to achieve more together than what each could do individually,” said BluHaptics CEO Don Pickering in a statement. “As companies begin to enjoy better control, improved safety, lower costs and more capabilities, this technology will quickly become an industry standard.”

“Our partnership with J2 Subsea is a strategic move that allows us to continue focusing on the development of future products with applications on land and in space, while at the same time positioning our subsea product for rapid growth,” said Luke Wissman, vice president of business development and special programmes for BluHaptics. n Contact: J2 Subsea

Tel: +44 (0)1224 248090 Email: aberdeen@j2subsea.com Web: www.j2subsea.com

August 2017

Resident experts

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ROVs AND UAVs

ROV looks to make the best of both worlds

W

HILE some subsea robotics firms are working on vehicles capable of travelling hundreds of miles, those in the inspection, maintenance and repair (IMR) market are working on solutions that stick closer to home – but are by no means less adventurous.

Advances in subsea power infrastructure, battery life and communications are ushering in a new wave of subsea-resident options, a few of which this issue of InnovOil will examine. As that happens, traditional categories begin to break down, as is evidenced by the latest technology trailered

by Saipem.

Developed by its somewhat secretive Sonsub unit, Saipem’s Hydrone robot is tricky to pin down. In a recent interview with Upstream Technology, Sonsub’s manager of remote control systems, Paolo Bonel, was emphatic, maintaining that “this not an AUV” but a new kind of hybrid – an autonomous ROV. More clarity is offered by a recent promotional video issued by the company.

Hydrone appears to combine a multitude of typical subsea technologies in one versatile platform. Although it may resemble a traditional light work-class ROV with two manipulator arms, it is able to operate tethered and untethered, human-piloted and autonomous. Saipem is betting on this flexibility as the future of subsea installation maintenance, using a robot that can adapt to each task as required.

The scope needed to achieve this is by no means limited. The company intends to harness a new kind of communications system based on optical, acoustic and electromagnetic signals, creating essentially a subsea wi-fi network. “We are developing a multi-mode modem that is able to manage these three physical communication systems and to automatically switch, or distribute the data, through these three different physical channels so that you have a more reliable

The Hydrone concept and control suite connection and more bandwidth in the communication,” Bonel told the publication.

One for all The demonstration video gives a better idea of what this could mean in practice. In one instance, a tethered Hydrone surveys a manifold before grabbing a torque tool skid to operate a valve. In another, human operators initiate an autonomous survey of a flowline, which is then carried out independently by a battery-powered, untethered system. After completing the survey, an operator can pilot the ROV back to base to recharge.

A final scenario envisions a leak or alarm scenario, allowing operators to dispatch a tethered system to inspect and monitor the situation, and intervene to turn a shutdown valve.

The Marghera-based unit intends to develop three distinct variations of the craft: the Hydrone-S, which would handle “advanced survey work”; a subsea-resident variation dubbed Hydrone-R; and the Hydrone-W, a battery-powered ROV that would be operated from shore.

NEWSBASE

Although the Hydrone concept is not entirely on its own, there are few platforms aiming for the same level of versatility as Sonsub, and perhaps even fewer heading towards actual trials. Perhaps that reflects the level of innovation required to put the system in the water These technologies are also to be included in another of Saipem’s ongoing ROV projects, Innovator 2.0. This is a heavy work-class system redesigned from the seafloor up, and for which sea trials were completed late in 2016. Although designed to be tethered to a vessel, this ROV includes a 6,600V power supply, allowing it to operate even with extremely long cable lengths of over 7,000 m. A 210HP electrical motor and high efficiency propulsion system gives the unit a bollard pull of 1,100 kg in either direction, a maximum speed of 3.5 knots and a lift capacity of over 600 kg.

A prototype Hydrone is scheduled to begin trials in in 2018. We will keep readers informed as a new vanguard of hybrid ROVs begins to take shape. n

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COMMENTARY

U

S independent EOG Resources, one of the country’s most prolific shale drillers, is ramping up its enhanced oilfield recovery (EOR) project in the Eagle Ford shale. The company is at the forefront of efforts to employ EOR techniques in shale. As encouraging as results have been, though, producers hoping to roll out similar technology across other shale places will face considerable challenges.

Slow recovery Against the backdrop of depressed oil prices over the past three years and increased competition, the US shale industry has remained resilient thanks to a combination of cost-cutting and improved technology.

While recovery rates have improved as a result of such efforts, they remain relatively low for shale wells compared with their conventional counterparts.

Though shale drillers are continuing to pursue efforts to boost recoveries, this is proving to be a challenging process. EOG is leading the way in using EOR techniques at its acreage in the Eagle Ford to deliver exceptional recovery rates from its wells.

“On a typical well, we expect to produce 30-70% more oil with EOR than with primary recovery,” EOG spokesman John Wagner told NewsBase Intelligence (NBI).

Previously, EOG has said that its costs for EOR in the region are roughly US$6 per barrel, or around US$1 million per well.

This number, said Wagner, “includes readily available natural gas, which we produce, and not much else”. Government tax credits for EOR projects, which include those in shale plays, help to relieve the financial burden even further.

Historically, conventional EOR processes typically involve separate injector and producer wells with floods of gas, carbon dioxide (CO2), water or steam. Conventional formations are more permeable than shale formations, allowing the fluids to flow more efficiently through the rock from the injector wells to the producer wells, displacing oil along the way.

Unusual environment Conventional EOR methods are not well-suited to use in shale formations. The Eagle Ford play is unique, though, because it has strong pressure containment both horizontally and vertically, noted Wagner.

Low permeability provides strong horizontal containment, while the formations above and below the Eagle Ford provide strong vertical containment. For EOG, this has made the play an ideal testing ground for its methods.

This year, the company is implementing

a 100-well plan across six different areas of its Eastern Eagle Ford acreage. No details of plans for 2018 have been provided, although given the low costs involved and the fact that each successive pilot has grown in size, a further ramp-up in EOR activity could be on the cards for the company.

As for the technology itself, EOG’s system is proprietary, and the firm has therefore been cautious about revealing its methods, especially as the system is believed to be the first successful shale EOR pilot in the country. However, Wagner did confirm that natural gas is used to re-pressurise the fields rather than the traditional injector-producer model of EOR. “We have not revealed a lot of details, but we have said that we are using readily available field gas in a miscible process, where gas dissolves in oil downhole forming a homogenous mixture, that the infrastructure and facilities put in place during primary development are key to executing EOR, and that production responds to the process quickly – within 2-3 months,” he said.

Taking risks This kind of innovation has been one of the US shale industry’s defining characteristics over the past decade. In part, this has been

Eagle Ford EOR: the big squeeze EOG Resources is pioneering the use of EOR in the Eagle Ford shale, and while results are favourable, other operators hoping to harness such techniques in shale plays will face considerable challenges, writes Sam Wright NEWSBASE

August 2017

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COMMENTARY

achieved with government backing, both in the form of tax breaks and support in research and development. However, the latter is now under threat, with the US Department of Energy’s (DoE) Office of Fossil Energy (OFE) facing heavy funding cuts under US President Donald Trump’s proposed budget plan.

The OFE has invested US$137 million into shale drilling research over the past 20 years. While this may seem a relatively small sum, all of its data and technology have been free to use for any company, resulting in a resource that has done much to help grow the industry. Its current projects include ongoing studies into subsurface analysis, aimed at improving recovery rates while lessening any possible environmental impact.

For many smaller drillers without their own R&D budgets, cuts to OFE funding could be a major blow. But in the case of EOR in shale plays, even larger operators with higher R&D budgets have struggled to get their projects off the ground. “[Majors] have an advantage in the sheer amount of capital they can internally deploy to the basins to get their programmes to scale, but this comes with some trade-offs,” said Wagner.

Organisationally, these firms are less

nimble and centrally run, leading to slower decisions and higher development costs.

Also, new movers in any basin need to organise their supply chains to operate cost-effectively. In the Permian, this involves water and sand sourcing, as well as product marketing and takeaway. It can be difficult for any new mover to overcome the existing entrants to achieve profitable agreements with suppliers and purchasers.

EOG, however, seems to be thriving in the middle ground. “We have a culture that encourages experimentation and intelligent risk-taking,” Wagner said. “As we have realised success with EOR, we have followed with larger pilots and continued to improve the process.”

Despite this positivity, for now it seems though that the process is limited to the Eagle Ford because of its superior pressure containment. Wagner said that while it was too early to quantify scale across the entire Eagle Ford, EOG could say that all of its pilots, which have been performed across different geographic and geologic settings, have been successful. While progress is still at a very early stage, the company’s results suggest that EOR can be a viable concept for the shale industry, and one that could make a major difference to recovery rates if it is harnessed effectively. n

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COMMENTARY

Rough’s closure should spur change in UK gas storage sector The permanent closure of Rough should act as the catalyst for the government to create an appropriate regulatory framework for gas storage, writes David Flanagan

R

ECENT confirmation that the 3.3 bcm Rough gas storage facility off the English coast is to close permanently will remove around 70% of the UK’s gas storage capacity.

The closure will be staggered, with socalled “cushion gas” being made available for withdrawal on a diminishing basis for the next two years. But after that, and given the length of time that is necessary to build new plants, the UK will inevitably see a decline in its total installed gas storage capacity.

As gas imports rise, and with Brexit raising questions about future energy interconnectivity with Continental Europe, the UK is now at a crossroads and facing serious questions about how to maintain the stability of its future gas supply.

A basic analysis of the situation would be to suggest that the UK should build new storage to replace Rough, while it is in the process of being taken offline. But there are questions hanging over that approach, not least investor appetite to plough cash into long-lead fossil fuel infrastructure projects as renewables continue to penetrate deeper into the energy mix.

Muted support In order to gain some perspective on the storage sector and how things might progress, NewsBase Intelligence (NBI) spoke to George Grant, founder and CEO of Stag Energy, which has the approval for

the development of the proposed 1.52 bcm Gateway gas storage plant off the northwest coast of England.

Grant first of all stressed that while Rough’s closure was to some extent anticipated, support from the UK authorities for new storage capacity had been muted.

“The age and vulnerability of the Rough gas storage facility has been recognised for a number of years,” Grant said. “In 2011, the Energy Select Committee determined that the UK needed more gas storage and required the development of an appropriate regulatory framework. Then, in 2012, the Defence Ministry concluded that it saw it as a significant weakness that a country that depends so heavily on gas has so little storage to offer resilience in the face of unexpected events.”

Despite these recommendations, though, no action was taken. “The government report on gas security in 2013 decided that no action was required. It is our hope that the closure of the Rough facility will precipitate a review of this position,” Grant said.

Time consuming But even if the government changes tack on the issue, rapid solutions are unlikely to emerge.

“It takes between five and seven years to build new storage capacity,” Grant observed.

“Even if a decision were taken to build today, a lead time of 12-24 months would be NEWSBASE

required to finalise designs and construction contracts, secure funding and mobilise the site. The UK is facing a very exposed position if we do not plan ahead to allow for these lead-in times,” he added.

The impending situation will mean the UK is in a far weaker position compared to its European neighbours. “The UK will have storage capacity equivalent to 2% of annual demand after Rough closes, compared with levels in mainland Europe upwards of 30%,” Grant said. “These levels simply do not provide adequate price protection for consumers.”

The Stag Energy CEO explained that the UK’s power sector was also becoming increasingly reliant on gas, and therefore had price exposure without adequate storage being built into the system. “With a higher proportion of intermittent renewable power within the UK energy mix, as well as the imminent closure of coal-fired plants, gas generation will provide the essential system back-up and gas will often set the price in the power market,” he said. “Historically, gas storage revenues were supported by the summer/winter price differential or spread.

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COMMENTARY Centrica’s Rough gas storage facility

But the spread has been squeezed in recent years owing to the global abundance of LNG on the market. That is not going to change in the near future and therefore market revenue opportunities for storage have been undermined.”

Stag and other companies have identified the need for commitment to a regulatory framework to ensure sufficient UK gas storage capacity is maintained. The company recommended in submissions to a parliamentary briefing about the storage market in late 2015: “Imposing an obligation on suppliers and shippers to hold a certain proportion of their gas in store ahead of every winter, through some form of Public Service Obligation (PSO), would be the simplest and most cost-effective solution, because it is market-based.”

The company argued: “A PSO sets down a long-term security standard, then leaves it to suppliers and storage operators to devise a workable solution that delivers the level and frequency of supply from gas storage that the market requires and is prepared to pay for.

The PSO approach does not require central procurement with the government and/

or UK regulator OFGEM picking winners and losers and underpinning the revenue of storage operators.”

Grant added that decision-making related to new gas storage should be informed by consultation with industry participants.

“On the demand side we see broad support from industry to maintain some minimum level of UK gas storage even if this were to result in a small cost addition on bills,” he said.

Grant went on to note that other parts of UK industry supported his position on the importance of storage to the economy.

He said Laura Cohen, a representative of the British Ceramic Confederation, had commented in the parliamentary briefing that “more UK gas storage underpinned by a gas security obligation on suppliers [PSO] is likely to provide the level of price and supply security insurance that our industry requires. Gas held in UK storage would reduce exposure to market disruption and international price volatility.”

What next?

Moving forward, Stag intends to redouble its NEWSBASE

efforts to move its Gateway project from the drawing board to the development phase.

“We have maintained engagement with the government with respect to gas security and continued to push for an appropriate industry structure,” he said. “We know the government commissioned further analysis on gas security from consultants CEPA last year, but this was in advance of the closure of Rough. We are keen to try to ensure that any such work is revisited in light of the recent announcements.”

Grant acknowledged that losses sustained by storage operators recently could act as a deterrent to new investment. But in response, he said, “The industry recognises that revenue prospects from the gas market alone are insufficient to support investment in new gas storage assets that have long-term investment and return horizons.”

Fundamentally, the closure of Rough has identified the UK’s relative weakness in terms of gas storage and supply. With potential supply fluctuation also being driven by Brexit, it appears imperative that an appropriate regulatory framework be given adequate consideration by the government. n

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NEWS IN BRIEF

Saipem awarded new E&C, FPSO contracts Saipem has been awarded a new E&C Offshore contract by Saudi Aramco for EPCI (Engineering, Procurement, Construction, Installation) activities and T&I (Trunklines & Installation) works in Saudi Arabia, under the Long-Term Agreement in force, renewed in 2015 until 2021.

The scope of work includes the design, engineering, procurement, construction and installation of a total of 19 jackets for the development of fields in Marjan, Zuluf, Berri, Hasbah, and Safaniya, among the most important offshore fields in the region of the Arabian Gulf.

Stefano Cao, Saipem CEO, commented:

“With this award, Saipem is further reinforcing its presence a highly strategic area such as the Middle East. The new contracts assigned by a long-standing customer like Saudi Aramco are also a strong and tangible sign of a major client’s trust in Saipem, in the high quality of its services and in the solid expertise the Company can ensure in the construction and installation of offshore platforms”.

Additionally, Saipem has negotiated the extension in Angola of the deployment of vessel FPSO Gimboa, inclusive of management and maintenance services, personnel, material and consumable supplies for 3 years, plus one optional year.

Finally, Saipem has defined change orders for projects in West Africa and in the Caspian Sea. Together, these new acquisitions, relevant to the second quarter, amount to a total of $500 million. n SAIPEM

Wisting gains regulator approval OMV Norge has been cleared by Norway’s Petroleum Safety Authority (PSA) to proceed with its latest appraisal of the Wisting oilfield in the Barents Sea. The PSA confirmed on July 6 that OMV Norge would spud wildcat well 7324/8-3 to appraise the Wisting Central III area some 315 km north of Hammerfest. The area lies in water depths of 394.5 metres, close to where OMV’s

Stefano Cao, Saipem CEO NEWSBASE

August 2017

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NEWS IN BRIEF

so-called “Wisting Extension” with 55% interest alongside OMV and Petoro with 25% and 20% respectively.

Wisting must clear a final investment decision (FID) in 2019-2020, though OMV executives have said they are comfortable with the “upper end” of its resource guidance.

The Norwegian Barents is thought to hold more than half of the country’s undiscovered hydrocarbon resource, with at least four major discoveries made there since 2010.

Explorers in the Norwegian Barents face less ice than other regions at similar latitudes, and much of the area’s prospectivity is situated in relatively shallow waters.

Wisting, for instance, lies in water depths of around 400 metres, which is likely to help keep a lid on the project’s development costs. Wisting features amongst a clutch of Barents prospects that are preparing for exploration and appraisal work this year. n Edited by Ryan Stevenson ryans@newsbase.com

TAQA awards Schlumberger EPCIC contract for Otter Field

Wisting Central II appraisal flowed at around 5,000 boepd last year.

Wisting Central III will aim to uncover “further” structural information to inform the project’s development. It is due to be spudded with the Island Innovator semi-submersible over 31 days from mid-August.

OMV believes Wisting could hold 1 billion boe, of which 200-500 million boe is likely to be recoverable.

It operates the prospect as part of PL 537 with a 25% interest alongside Statoil (35%), Idemitsu (20%) and Petoro (20%). Statoil was awarded the adjacent licence PL 855 during the 23rd Norwegian licensing round, operating the

OneSubsea, a Schlumberger company, today announced the award of an engineering, procurement, construction, installation and commissioning (EPCIC) contract for a subsea multiphase boosting system by TAQA for the Otter field in the UK North Sea. Through the EPCIC contract, OneSubsea and its Subsea Integration Alliance partner, Subsea 7, will supply and install a subsea multiphase boosting system including topside and subsea controls, as well as associated life-offield services. The project will result in a 30-km subsea tieback to the TAQA-operated North Cormorant platform. This will be the longest subsea multiphase boosting tieback in the UK North Sea. “This fit-for-purpose subsea boosting system will improve TAQA’s ultimate recovery from an existing asset, through a capitalefficient long tieback,” said Mike Garding, president, OneSubsea, Schlumberger. “We look forward to working with TAQA to maximize the full value of the Otter field.”

OneSubsea and Subsea 7 will deliver a turnkey integrated project from design through supply, installation and commissioning. n SCHLUMBERGER

NEWSBASE

ADES lines up Egyptian drilling work Eni has contracted a jack-up for work offshore Egypt, from ADES International, it was announced on July 3. London-listed ADES said the Admarine 88 had won new work, while the contract on the Admarine V jack-up had been renewed.

Both contracts came from Belayim Petroleum (Petrobel), a joint venture’s between Eni’s IEOC and Egyptian General Petroleum Corp. (EGPC). The rigs will work on Eni’s areas in the Gulf of Suez. The Admarine 88 is going to carry out a three-month campaign, with the potential for extension on a well-by-well basis, ADES said.

The Admarine V rig has been renewed for six months on a call-out basis, following the expiry of its recent contract. There is also an option for a six-month extension.

“We are excited to renew our partnership with one of North Africa’s leading joint ventures with whom we have a 10-year track record of success. Eni and other major international oil companies operating in our present day geographies of Saudi Arabia, Algeria and Egypt appreciate the exceptional value for money we offer by deploying fit-for-purpose refurbished legacy rigs and world-class crews to assets in shallow, non-harsh environments,” ADES’ CEO, Mohamed Farouk, said.

The rig provider went on to say it had struck a deal on its Admarine VIII jack-up for work with Fanar Petroleum, under an existing contract with South Abu Zenima Petroleum (Petrozenima).

The work involves additional work on the North July well, with the hope of improving productivity. This work should begin before the end of July, the company said.

ADES did not provide details on what dayrate had been agreed under these contracts.

According to its prospectus, published this year, the jack-ups are leased at a rate of US$45,00065,000, with the Egyptian assets at the lower end of that range.

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NEWS IN BRIEF

Georgia launches tender for UGS project

The ADES CEO went on to say the company’s ability to seal deals during a period of low oil prices was a “testament to the strength of our business model and the quality of our drilling and workover services at highly competitive rates”.

Dubai-based ADES began trading on London’s main market in May. The company has nine offshore rigs, three onshore rigs, plus onejack-up barge and one mobile offshore production unit (MOPU), with an average age of 39 years. Revenues and profits have increased over the last three years, but day rates have declined. n Edited by Ed Reed edreed@newsbase.com

Chiyoda poised to partner with Subsea 7 JAPANESE engineering outfit Chiyoda appears to be on the verge of forming a business alliance with Subsea 7 after offloading the troubled EMAS Chiyoda Subsea (ECS) to the UK-based offshore contractor.

ECS became a wholly owned subsidiary of Subsea 7 on June 29, four months after filing for Chapter 11 bankruptcy protection in the US. The company was established on March 31,

2016 as a 50:50 joint venture between Chiyoda and Singapore-based offshore services provider Ezra Holdings. Japanese shipping firm NYK Line later acquired a 25% stake, reducing Chiyoda and Ezra’s holdings in ECS to 35% and 40% respectively.

ECS’ short lifespan came amid a prolonged slump in global oil prices, dealing a serious blow to Chiyoda’s efforts to expand its offshore upstream business and reduce its heavy reliance on the LNG plant business.

Chiyoda, one of the world’s biggest LNG plant contractors, slipped into the red for the first time in 16 years in the financial year ending March 31, owing to ECS’ losses. Subsea 7’s acquisition of ECS was confirmed by the US Bankruptcy Court for the Southern District of Texas and became effective on June 29.

“Chiyoda will proceed to discuss with reliable partners, such as Subsea 7, the development of its offshore and upstream business by using experiences gained to date through ECS (EMAS Chiyoda Subsea),” the Japanese company said on June 30.

In July 2013, Chiyoda announced its acquisition of a majority stake in UK-based upstream service provider Xodus Group. In October 2013, Chiyoda also announced its participation in the development of two offshore oil blocks in Gabon by acquiring a 25% stake in MPDC Gabon. n Edited by Andrew Kemp andrew.kemp@newsbase.com

NEWSBASE

GEORGIA has kicked off a tender for the construction of its first ever underground gas storage (UGS) unit, a project aimed at bolstering the country’s energy security.

In a statement on July 14, state-owned Georgia Oil & Gas Corp. (GOGC) announced it was looking to secure engineering, procurement, installation and commissioning (EPIC) services for the building of a storage facility at the depleted Samgori South Dome oilfield near Tbilisi. It has invited interested contractors to enter a pre-qualifying round, during which their relevant experience and financial capability will be assessed.

Companies selected during this phase will then need to submit commercial proposals.

The work on offer includes the drilling of two exploration wells that will evaluate the project’s scope, along with the completion of four monitoring wells. GOGC is also tendering the installation of a gas treatment and compression station at the site, along with power supply equipment and oil, water and gas pipeline systems. Construction work is slated to begin in early 2018 with the aim of completing the facility by 2021.

Georgia began drawing up plans for its own UGS facility a decade ago, but the project has only gained traction in recent years, owing to rapid growth in the former Soviet state’s demand for gas. The country mostly relies on

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NEWS IN BRIEF Yokohama LNG town gas supplier, just south of Tokyo

imports from Azerbaijan to meet its gas needs, and has sought to limit purchases from Russia for political reasons. However, because it lacks domestic storage capacity, Georgia has often been forced to secure Russian gas whenever there are production outages at Azerbaijan’s Shah Deniz gas field in the Caspian Sea. According to a design drawn up by France’s Geostock last year, the Samgora UGS facility willhave a capacity of 210-280 mcm of gas, or 10-15% of Georgia’s annual gas intake.

The Samgora field is situated just 30 km from Tbilisi and in close proximity to the South Caucasus Pipeline (SCP), which carries gas from Azerbaijan. n Edited by Joe Murphy josephm@newsbase.com

Minister of Energy and Natural Resources and Director General of Georgian Oil and Gas Corporation

Tokyo Gas investigates small-scale LNG TOKYO Gas is reportedly looking at small-scale LNG delivery and storage solutions that can be rolled out across many of the Philippines’ 2,000 inhabited islands. The company is studying the feasibility of installing small LNG storage and power Vgeneration facilities on remote islands in the Philippines, the Nikkei reported on July 17.

The Japanese business daily added that the plan envisions small LNG vessels making deliveries every week to two weeks to the installations that are projected to cost tens of millions of US dollars.

The Nikkei added that switching from fuel oil to LNG as a power generation feedstock should result in lower electricity bills for local end-users.

Tokyo Gas, backed by Japan’s Ministry of Economy, Trade and Industry (METI), will study the project’s commercial viability until the end of spring 2018.

The Philippines has been looking at its LNG import options for some years now. The country’s biggest gas field, Malampaya – which fuels 2,700 MW of power generation capacity, is predicted to run dry by 2024. As such, the Southeast Asian country wants to take advantage of swelling global gas supplies that have driven prices for the frozen fuel down.

Prices on the spot market for Asian LNG were around US$5.40 per mmBtu (US$149.36 per 1,000 cubic metres) on July 14 – down more than 70% from a peak of US$20.50 per mmBtu (US$567.03 per 1,000 cubic metres) in February 2014.

NEWSBASE

This price collapse has also prompted major buyers of the fuel, such as Tokyo Gas, to reevaluate their contracts. Just last week a senior general manager for gas resources at Tokyo Gas, Takashi Higo, revealed that his company was looking for more favourable terms as it begins to negotiate the renewal of existing supply contracts. The manager added that Tokyo Gas was reviewing the terms of its 12 supply contracts.

“We have re-negotiations under way, including price review,” Reuters quoted Higo as saying at an energy conference on July 13. “There will be tough negotiations [with suppliers] and it will take a lot of time.” n Edited by Andrew Kemp andrew.kemp@newsbase.com

Yinson has plans for six new FPSO projects MALAYSIAN floating production, storage and offloading (FPSO) vessel specialist Yinson will target six new projects in the fiscal year to January 31, 2018 in its core markets of Asia and Africa, the firm’s CEO, Lim Chern Lim, said last week.

Lim was speaking after Yinson agreed to offload its 26% stake in the Ghanaian FPSO for the Offshore Cape Three Points (OCTP) project earlier this month.

Yinson will bank US$104-117 million for the stake under the deal with Japan’s Sumitomo, Kawasaki Kisen Kaisha, JGC and the Development Bank of Japan.

Lim noted that Yinson’s cash account

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held633.92 million ringgit (US$147.5 million) as of January 31, 2017, while its order book contained US$3.7 billion at present. Yinson’s backlog appears to be comparable with the 15 billion ringgit (US$3.6 billion) registered by a competitor, MISC, for lease receivables on its ships as of December 31, 2016. But it is substantially smaller than the 39.5 billion ringgit (US$9.19 billion) order book amassed by Bumi Armada at the beginning of this year.

With scant orders from upstream developers reeling from the industry depression, Malaysian services firms have been forced to hunt efficiencies while also considering acquisitions and mergers. But there are signs the segment might be recovering as an improved sentiment on oil prices encourages developers to advance investments in the hope of capturing upside.

“We do see more bids than before oil prices initially went down, there were not many

projects up for bidding,” he said. “After we won Ghana, for two years there were no projects awarded. [Now] we do see projects starting to be awarded again.”

Yinson hopes to use the Japanese consortium’s contacts to expand into new international markets, with Lim remarking on July 10 that each partner offered “related strengths”. In particular, Sumitomo operates a global energy and infrastructure portfolio which includes US tight oil and gas interests, though its exposure was reduced following heavy losses in 2014.

“We can use Sumitomo’s network to go into a new market,” Lim was quoted by The Edge Markets as saying, “They know the local culture, they know the local rules [and] that will give us a head start.” n Edited by Andrew Kemp andrew.kemp@newsbase.com

Xodus wins subsurface contract with Cairn Oil and Gas in India Xodus Group has won a contract with Cairn Oil and Gas of Vedanta Ltd to conduct exploration and appraisal work on its Rajasthan block in north-west India over the next two years.

The first stage of the work will focus on delivering new drilling prospects and an exploration drilling plan, in partnership with Cairn Oil and Gas’ in-house team. Subsequent stages, which will likely commence in 2018, will require project management of the drilling programme in the field as well as subsurface analysis of drilling results.

The work will largely be undertaken from Xodus’ offices in London and The Hague with regular visits to Cairn Oil and Gas’ offices near New Delhi for workshops.

Xodus Group CEO, Wim van der Zande said: “We are pleased to be supporting Cairn Oil and Gas in the pursuit of increasing discovered hydrocarbon resources in the Rajasthan block, which is of major significance to the country.

At Xodus, we continue to build our experience in India and this work will be delivered with the expertise of our fully integrated team and specialised technology.”

Cairn Oil and Gas operates over a quarter of India’s domestic crude oil production. The Mangala, Bhagyam and Aishwariya (MBA) are the three largest finds in Rajasthan. The oil and gas fields in the Rajasthan Block constitute Cairn’s key assets in India. The Mangala field - considered to be the largest onshore hydrocarbon find in India in the last two decades - was discovered in January 2004. This was followed by the discovery of the Aishwariya and Bhagyam fields. n XODUS

CNPC makes efficiency gains at Dagang CHINA National Petroleum Corp. (CNPC) claims to have made drilling more efficient at the onshore Dagang cluster east of the Bohai Sea, while also touting the implementation of

Xodus Group CEO, Wim van der Zande NEWSBASE

August 2017

InnovOil

page 37

NEWS IN BRIEF The NTK Victoria

new stratified technology for oil testing.

The NOC said on June 29 that it had tested well plates in “deep field” conditions to shave seven days from the time needed to complete the Dagang Banqiao test probe.

This was said to have saved the company 400,000 yuan (US$58,800) on construction costs. Drilling the Dagang Banqiao prospect required stratified technology so that CNPC could collect data on two separate layers situated 9.8 metres apart.

CNPC said using a traditional testing approach would have risked obscuring the logs of both layers, and could result in unnecessary pollution if the two reservoirs were breached synchronously.

Dagang Banqiao is the latest exploration effort at CNPC’s onshore Dagang Oilfield cluster, which was discovered in 1964 to the north of Tianjin and Hebei Provinces. As of 2005, Dagang was capable of producing 4.8 million tpy (96,000 bpd) of crude plus 100.4 mcm per day of gas.

CNPC aimed to complete improvements between 2006 and 2007 to hold Dagang’s overall annual output above 5 million tonnes of oil equivalent per year (100,000 boepd).

Work thereafter turned to expanding Dagang’s undeveloped reserves over what CNPC said could be a five to eight-year period.

On June 23, CNPC said daily crude output

at one of Dangang’s latest fields, Block 1608, was averaging around 181 tonnes (1,326 bpd) from five wells.

The importance of the Dagang exploration lies in its ability to meet fuel demand around China’s populous Bohai Economic Region, which includes several satellite areas around Beijing, such as Tianjin and Hebei provinces.

Close by in the offshore Bohai Sea, CNOOC Ltd has made a number of discoveries over the years, with recent finds being the Caofeidian 6-4-1 in 2014 and Bozhong 8-4 in 2013.

Edited by Andrew Kemp andrew.kemp@newsbase.com

VisualSoft selected for the world’s most advanced cablelaying vessel Forum Energy Technologies has announced a new contract that will see its market-leading pipeline and cable survey software installed on the world’s most advanced cable laying support vessel, the NKT Victoria.

NEWSBASE

Two VisualSoft Four Channel High Definition Digital Video Systems (VisualDVR MCHD) will be supplied to iSURVEY Group, a leading provider of survey and positioning services to the global oil and gas and telecommunications sectors. The first vessel installation for the newest system in the VisualSoft range, is to be utilised on the NKT Victoria in the Moray Firth.

The NKT Victoria (DNV-GL Class) is a 140m x 30m DP3 top-of-the-range diesel electric vessel with 1600m2 of deck space and two large offshore cranes. The high capacity cable lay system features a battery energy storage system to assist the cable loading in the event of failure of the shore power used during loading.

The VisualSoft suite is a modular range of software applications designed specifically for use during subsea structure and pipeline inspections.

The VisualDVR MCHD system will provide the project team with up to four channels of high definition video recording complete with built in dynamic overlay and the ability to distribute live video and overlay channels without the need for additional hardware.

Video files are recorded using H.264 encoding for optimum storage efficiency and playback compatibility. n VISUALSOFT

page 38

InnovOil

What next …?

To make enquiries about any of the products or technologies featured in this edition, use this list of vital connections

The REMORA project sets a new precedent for versatile, autonomous subsea robotics systems. To learn more, or to discuss future collaborations, please contact Prof. Roberto Galeazzi on +45 4525 35 49, or email rg@elektro.dtu.dk Those with unconventional technologies suitable for the US Department of Energy’s new research grants are advised to read the additional information available via the National Energy Technology Laboratory website.

If the SkyOne drone and SkyX Solution could help you with your asset monitoring programme, contact the company at contact@skyx.com, or visit skyx.com For more information about BluHaptics’ augmented robotics technology, and its distribution via J2 Subsea, contact the company at +44 (0)1224 248090 or email aberdeen@j2subsea.com The Elios drone sets a new benchmark for safe inspection of enclosed environments. To learn more about the system, contact Flyability via +41 21 311 55 00 or email sales@flyability.com To make an enquiry regarding the JFSE MultiROV mass flow excavation system, contact enquiries@jf-se.com Minox Technology is dramatically scaling down the weight, footprint and energy consumption of gas dehydrating facilities.

To learn more, get in touch with CEO Bjørn Einar Brath on +47 35 11 57 00 or via ber@minox.no

NEWSBASE

August 2017

VAxplorer Extreme torques, extended reach

voestalpine Tubulars GmbH & Co KG www.voestalpine.com/tubulars

voestalpine ONE STEP AHEAD.

An asset to energy professionals

Published by vNewsBase

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