Aberdeen-based Helix Well Ops UK (Well Ops), a business unit of international offshore energy company Helix Energy Solutions Group (Helix ESG), is expanding its Europe and Africa well intervention fleet with an investment that will create 60 jobs.
A leading global provider of subsea well intervention, Well Ops will take control of the mono-hull well intervention vessel Skandi Constructor in spring 2013, after agreeing a three-year charter with DOF Subsea.
The move to strengthen Well Ops’ regional fleet, which currently includes the 132-metre (433ft) long Well Enhancer and the 114-metre (374ft) long MSV Seawell, will lead to the creation of approximately 50 jobs offshore and a further 10 onshore over the next nine months. At the moment the firm employs 70 staff in Aberdeen and a further 300 offshore.
Launched in 2009, Skandi Constructor is a 120-metre (393ft) long Ulstein SX121 DP3 mono-hull well intervention vessel that features the new X-bow design. The 8,500-tonne vessel accommodates up to 100 personnel and is capable of working in depths of up to 3,000 metres (9,842ft). It has a deck capacity of 1,470 square metres (15,822 sq ft) and features an 8m x 8m (27ft x 27ft) moon-pool, a 150-tonne crane, a multi-purpose tower with 140-tonne lift capability and two work class ROVs.
Well Ops will build and test, ready for use, a specially designed version of its 7⅜” subsea intervention lubricator (SIL) to enable subsea well interventions to be undertaken from Skandi Constructor. The SIL is a single trip well intervention system that provides well access, while managing containment when the well is ‘live’ and under pressure. The SIL is configured to undertake work through all types of subsea xmas trees. The vessel and SIL will allow Well Ops to provide its regional clients with a solution for deeper water wells and well interventions, which to date has been limited within the mono-hull vessel market.
Steve Nairn, Well Ops’ regional vice president of Europe and Africa, said: “Well Ops is extremely proud to announce the addition of a third vessel to our fleet and it underlines our commitment to providing well intervention services. Skandi Constructor strengthens our offering internationally and expands our well intervention service capability.”
The need for a third vessel in Well Ops’ fleet has been driven by demand from operators in the North Sea and in other oil and gas producing provinces. The firm recently secured contracts from a number of the North Sea’s major operators to provide light well intervention and associated subsea services from its existing vessels between 2013 and 2015.
Internationally, it has also received strong interest from operators, particularly in West Africa. This follows Well Enhancer’s deployment to the region earlier this year, where it completed what was believed to have been the region’s first well intervention project from a mono-hull vessel.
Mr Nairn added: “This is an exciting time for the company and the demand that we are witnessing is illustrative of the level of service and expertise that we can offer clients. As operators continually seek to make their operations more time and cost efficient, it is encouraging that more are turning to mono-hull vessels to conduct well intervention work.
“Our experience of providing an alternative to rig-based intervention systems has been built up over 25 years. MSV Seawell helped to pioneer light well intervention in the North Sea and we have built on this over recent years with Well Enhancer, which was the first mono-hull vessel capable of delivering coiled tubing intervention.”
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There are great things happening aboard the vessel “Havila Phoenix” nowadays. During the last two years there have been installations and tests of a whole new system likely to revolutionise the offshore light well intervention market.
The vessel, a Havyard 858 design, is designed and constructed by the ship technology group, Havyard Group AS, and owned by Havila Shipping, both located in Fosnavåg at the west coast of Norway. The offshore construction vessel was delivered from Havyard Ship Technology in Leirvik, Norway in 2009.
The vessel has over the last year-and-a-half been working on a contract for Fugro-Salt Subsea, part of the massive Fugro group, which is a Dutch-based corporation with more than 14.000 employees spread across 60 countries. Fugro-Salt Subsea cooperates with Expro in terms of developing the new “AX-S”-system aboard Havila`s advanced construction vessel.
So far the development of this new system has been running for seven years and cost NOK 1.2 billion in research and investments in ground-breaking new technology. The breakthrough appeared around a month ago when tests in the Norwegian Onarheim fjord proved very successful.
“AX-S” is a brand new system for well intervention involving remote-controlled subsea tools. The new system is, according to both the Havila management and the management of Fugro-Salt Subsea, a revolutionary system using solutions so far never utilised in subsea operations from a construction vessel. This involves employing extremely advanced remote-controlled subsea tools during well intervention that can handle up to eight different tools within the same operation, as well as using a light fibre rope instead of heavy steel wires. These are the main elements of the recent innovation. Should the system also win approval in a business sense, it could have a major impact on the offshore light well intervention market.
STABLE HAVYARD VESSEL
In the last year-and-a-half the 110 metre long vessel, a ship now docked in the port of Montrose between Dundee and Aberdeen, Scotland, has looked more like a research station than an offshore vessel. Havila Phoenix has been outfitted with a 35 metre tall tower and several modules on deck with a combined weight of over 500 tonnes. And there is no coincidence that the Scottish group has chosen a Havyard 858 design for this unique project.
– We needed a big, solid and modern vessel, and Havila Phoenix has lived up to all our expectations. If we fully succeed with this project we will likely be looking to acquire vessels of a similar design, but we will then need to be part of the planning straight from the start and get more of the system directly integrated below deck, says Operation Manager Darren Bown of AX-S.
The captain of Havila Phoenix, Leif Magne Lynge from Gursken, Norway, confirms that the vessel still remains impressively stable despite the enormous added weight.
– Yes, things have been working really well and the vessel also performs really well for its purpose. Facilities are also excellent, says Lynge who`s been captain aboard the vessel since the initial delivery. Captain and crew are definitely looking forward to heading out to the North Sea in order to start using this exciting new system.
UNIQUE REMOTE-CONTROLLED TOOLS
Michael Earlam of Fugro-Salt Subsea informs that there are several factors making the AX-S system a world sensation. In addition to the utilization of fibre ropes instead of wires for AX-S deployment, Earlam emphasizes the remote-controlled handling and deployment of the subsea packages with the ability to deploy 8 subsea tools is each time is unique.
– By using traditional well intervention equipment you can only perform one task at a time before the equipment needs to be raised to the surface in order to swap tools and then perform a subsequent operation. The equipment used in the AX-S system manages to handle eight various tools while on the seabed, without having to be raised to the surface to swap over any tools. This makes the operation much more effective and cost-efficient, Michael Earlam informs.
And after seven years of preparation the system is nearing its baptism of fire. In September, Havila Phoenix with 500 tonnes of “subsea factory” on deck will be heading out to work in the British sector of the North Sea.
– Yes, following the successful commissioning of the AX-S system on NUTEC’s “cold well” in Onharheimsfjord, south of Bergen, during April and May be performing operations in the North Sea, the Operations Manager for AX-S, Darren Bown of Expro, confirms.
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The company said the gas was originating thousands of meters below the sea bed, which engineers said might mean that a relief well – one possible option to stop the leak – could take months to drill.
“The leak is from a (gas) well that was plugged one year ago and from a rock formation in about 4,000 meters depth,” a company spokeswoman in Aberdeen said on Thursday.
A flare needed to relieve pressure in the platform by purging excess gas has continued to burn less than 100 meters from the leak, and engineers said changes in wind and weather could lead to an explosion.
“The wind is pushing the gas cloud in the opposite direction (from the platform). At this time, the circumstances are rather favorable,” Jacques-Emmanuel Saulnier, head of communication at Total said in an interview published on Total’s website.
“A gas cloud is always a fire hazard,” he added.
Total kept two fire-fighting ships in a state of readiness outside a two-mile exclusion zone, which was set up to protect marine traffic, a Total spokeswoman said.
The company has also brought in a robot vessel, not yet deployed, to scan the sea bed for signs of spillage, she said.
Total has not yet found a way to stop the gas leak. A team of international engineers assembled by the embattled French oil company are drawing up plans to tackle the leak and prevent the flare from coming into contact with the gas cloud, the spokeswoman said.
The platform is currently off limits to the engineers, however, given the toxic and explosive plumes pumping out of the wellhead.
The leak started on Sunday and forced the evacuation of all 238 workers from the platform, which sits in waters less than 100 metres deep and 240 km (150 miles) off the east coast of Scotland.
PRESSSURE SEEN FOR RELIEF WELL
Total warned on Tuesday it could take six months to halt the flow of gas. The company previously stated it hoped the leak would die down from natural causes as reservoir pressure drops.
“What we know is that the leak is not coming from a well dug by Total but from a naturally occurring pocket of gas located just above one of our wells,” said Total’s Saulnier.
The depth of the non-producing reservoir that is feeding gas to the Elgin platform via compromised layers of piping suggests, however, there is more gas present rather than less, piling pressure on Total to drill a relief well, an engineer with knowledge of the matter said.
Relief drilling would require boring through 4 kilometers of rock with painstaking mathematical precision, because it must intercept the gas pocket at exactly the right point, requiring constant alterations in course, the engineer said.
The leak, one of the biggest in the North Sea for decades, could well inspire tougher safety regulation in due course, according to experts. Britain’s health and safety watchdog said it was considering launching an investigation into the incident, while union officials said the frequency of offshore safety lapses had become intolerable.
Memories are still raw in the North Sea industry of the Piper Alpha platform fire 24 years ago, which killed 167 people in the world’s deadliest offshore oil disaster and led to a major regulatory overhaul.
Total as well as UK authorities have described the expected environmental impact from the plume of gas and a spreading sheen of light oil on the water as “minimal”, although environmental experts said much of the gas “cocktail” would be either flammable or poisonous at close quarters.
Total’s shares have lost about 9 percent in the wake of the incident. They were trading at 37.63 euros at 1305 GMT.
Analysts said the French oil major could face costs of up to $10 billion if its North Sea gas leak leads to an explosion and nearly $3 billion if it takes months to fix.
However, Jefferies securities and investment bank said in a research note that data that had emerged on the spill, which “has further convinced us that the spill consequences should be less than the most pessimistic market estimates and hence that the US$9.7 billion sell-off in the stock since Monday is overdone”.
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The gas has been flowing since Sunday, March 25th, when Total evacuated all the personnel from the Elgin platform. The precise cause of the gas leak, that has been flowing approximately 240 km east of Aberdeen, is yet to be identified.
According to The Telegraph, experts have warned that the gas cloud which can be seen is very flammable and they described the situation as a disaster waiting to happen because the flare on the Elgin platform is still ongoing.
Total explains that the flare is an integral part of the platform’s safety system, and it is used to safely evacuate all the remaining gas from the platform. The company says that the flare does not pose a threat, because the winds are taking the gas cloud away from the open flame.
“The wind is forecast to remain in its current direction for the coming days. You can be assured that this is being reviewed on a constant basis and should this change any impact is being assessed. In parallel we are investigating solutions to extinguish the flare if it does not burn out by itself.”
Elgin and Franklin are two high pressure/high temperature gas and condensate fields in the Central Graben Area of North Sea. Total E&P UK Limited owns 46.17% and is operator of both fields through its wholly-owned subsidiary EFOG and its average share of production was around 60,000 barrels of oil equivalent per day in 2011.
Elgin/Franklin facilities comprise two wellhead platforms, one on Elgin and one on Franklin and a Production/Utilities/Quarters (PUQ) platform. The PUQ is on the Elgin field and is linked to the Elgin wellhead platform by a 90-metre bridge.
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Helix Well Ops UK (Well Ops), a business unit of international energy services company Helix Energy Solutions Group (Helix ESG), has successfully completed a three-month campaign for West Africa’s first well intervention work and subsea well operations conducted from a mono-hull intervention vessel.
Operating the 132-metre (433ft) long Well Enhancer, Well Ops performed a subsea tree change out, well suspensions, well maintenance and production enhancement on seven wells in water depths of up to 471m (1,545ft). This project represents the deepest operation conducted from Well Enhancer since it joined the fleet in 2009.
The Well Enhancer’s arrival in the waters west of Africa marked the emergence of mono-hull-based well intervention services in a region that is experiencing rapid development. Compared to rig-based methods, intervention programs delivered from mono-hull vessels provide numerous operational and cost benefits to operators.
Steve Nairn, Well Ops’ regional vice president of Europe and Africa, said: “Providing operators with alternatives to rig-based well intervention brings new cost and time efficiencies to West African oil and gas projects. Because Well Enhancer deploys more quickly than a rig, and is designed specifically for well intervention work, she reduces down time and helps operators return as quickly as possible to their business of oil and gas production.”
Well Enhancer provides remotely operated vehicle (ROV), saturation diving and riser-based and riserless well intervention services. It features a 150-tonne multipurpose tower which is capable of deploying slickline, e-line and coiled tubing tool strings for well interventions in water depths of up to 600m (1,968ft) for wireline and 200m (656ft) for coiled-tubing. The vessel’s other key features include a 7⅜” subsea intervention lubricator which is a conduit for both live well access and well containment, an 18-man saturation diving spread, work and observation class ROV’s, kill pumps, and a 100-tonne crane which is rated to operate to water depths of 600m (1,968ft).
A business unit of Helix Energy Solutions Group, Aberdeen-based Helix Well Ops UK provides a range of well operation and decommissioning services using specialist vessels and innovative equipment. Launched in 1987, MSV Seawell was a pioneer of the light well intervention market and completed its first wireline intervention project in 1988. In 2009, Well Ops expanded its fleet with the launch of Well Enhancer, a 132-metre (433ft) long well intervention and diving vessel. The company employs 70 staff in Aberdeen and a further 300 offshore.
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TETRA Technologies, Inc. has acquired Optima Solutions Holdings Limited (“Optima”) for GBP 40 million (approximately $62.7 million equivalent) plus contingent consideration to be paid in the future depending on profitability.
Optima is a leading provider of rig cooling services and associated products that suppress heat generated by the high-rate flaring of hydrocarbons during offshore well test operations. Established in 1999, Optima has grown rapidly and has served a diversified customer base in over forty countries from operational bases in Aberdeen, UK, and Perth, Australia. Optima’s expectations for continued growth are underpinned by excellent long-term relationships with key customers, increasing international expansion, and a robust market outlook.
Optima’s rig cooling systems provide safety from the extreme temperatures generated during flaring operations and enable high-rate well test operations to be performed without compromising installation integrity, installation operations and personnel safety. Optima’s rig cooling packages employ patented nozzle technology and a wide range of associated pumping equipment that provide users with exceptional performance, reliability and safety.
“With this acquisition, we are accelerating our strategic goal of offering our customers a broader range of well completion and production testing services, and we are expanding our presence in many significant global markets. Optima is a strong complement to our existing portfolio of well completion and production testing services, and we believe we can add value for Optima’s customers through our experience in, and understanding of, those businesses. We are impressed with the relationships and market position that Optima has built and intend to support them within the TETRA family. In addition, we expect this acquisition to be accretive to our consolidated earnings in 2012,” commented Stuart M. Brightman, TETRA’s President and Chief Executive Officer.
Managing Director and founder of Optima, Jamie Oag, stated, “We are very pleased with our new ownership structure. We see this as the next phase in our strategic plan, increasing Optima’s global presence in a manner consistent with our best in class safety and service quality performance standards.” Mr. Oag went on to say that, “Both my fellow founder, Peter Bartholomew, and I, will remain with Optima, along with the remainder of our experienced management and operations teams.”
Simmons & Company International served as financial advisor to TETRA and Ernst & Young served as financial advisor to Optima.
TETRA is geographically diversified oil and gas services company focused on completion fluids and other products, after-frac flow back and production well testing, wellhead compression, and selected offshore services including well plugging and abandonment, decommissioning, and diving.
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Aberdeen-based oilfield services firm Coretrax Technology Limited has secured over £1.2million of contracts since the start of the year and expanded its team to 12 people.
Coretrax specialises in innovative oilfield services to the completion, cementing, abandonment and wellbore clean up sectors both in the North Sea and globally. The contract wins are for projects in the North Sea utilising Coretrax’s innovative wellbore clean up tools and chemicals.
The team in Aberdeen has also expanded with the appointment of a new business development manager and offshore supervisor both bringing many years of oil industry experience to the company. Coretrax plans to recruit a further 6-8 new staff in 2012 including a second graduate in design engineering.
Kenny Murray, director and founder of Coretrax, said: “We have had a really promising start to the year and I’m delighted with the new members who have joined the Coretrax team. Our focus this year is continual R&D to expand our range of products and services to provide solutions to operators with our team of engineers globally.
“Our innovative approach to wellbore clean up has also led to successful projects globally and we are completing successful contracts in Africa, Middle East and Asia. We will continue to expand both internationally and in the North Sea with on-going recruitment and new premises this year.”
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The ship was delivered from Ulstein Verft to Blue Ship Invest on 19 January, and entered the spot market in the British North Sea sector directly. After only days of operation in the spot market, the vessel will enter into a long-term contract as of next week.
Remøy Shipping has technical and commercial management of the vessel. “We are now in transit to Aberdeen where we will load before returning to the field,” reported Captain Trygve Valø yesterday afternoon. After a week in operation, the Captain and his crew are very pleased with the vessel’s performance. “Everything is working well – she is a good ship,” he concludes.
Frank Strandebø in Blue Ship Invest joined the vessel her first week in operation. He himself is a captain and got to test the ship in 8 metre waves: “It takes eleven hours from Aberdeen to the oil rig we have been working for, and with some spells of bad weather en route, we got evidence of the ship’s great sea-keeping qualities. She has soft and smooth movements and the X-BOW allows her to keep a higher constant speed in head sea.”
Strandebø greets the Blue Fighter project team in Ulstein Verft with the following: “This vessel is top notch. Everything has been working perfectly on the first trip, so all credit to the project team for the work you’ve done.”
The ship has a length of 83.4 metres and a beam of 18 metres. It has a cargo deck of 875 square metres and a load capacity of 4200 tonnes (dwt). Among others the ship meets the requirements of DNV’s Clean Design notation. It has a maximum speed of circa 15 knots and modern accommodation for 24 persons.
Offshore Energy Today Staff, February 2, 2012; Image: Ulstein Group
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