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Table of contents

In each case, after a short period of time, the mission was compromised and the. These two saildrones have recently successfully navigated winter conditions through the Drake Passage and entered the South Atlantic Ocean. Unlike SD , SD and SD are equipped with scientific echo sounders to study fish biomass in addition to the standard atmospheric and oceanographic standard instruments SD and SD were redeployed in May with square wings.

Future plans in the Southern Ocean Saildrone is building a global fleet of unmanned surface vehicles, targeting planetary coverage. The cactus is well known for its ability to survive without much water,but drowning it in the ocean may prove to be a game changer for the oil and gas industry. Inspired by the Saguaro cactus, LGS was originally designed by engineering consultants AMOG, after being approached by Matrix to help solve the long-standing issue of vortex induced vibration VIV and drag caused by currents on drilling risers. The success of the technology soon led to the expansion of LGS to free span correction of subsea pipelines in the form of retrofittable shrouds.

Coastal science and societies

The remotely installed LGS shrouds wrap around unsupported sections of oil and gas pipelines, with their unique shape acting to reduce VIV caused by strong ocean currents on exposed pipelines. This problem can occur when oil and gas pipelines running along seabeds develop unsupported free span sections due to an uneven seabed, failures in artificial pipeline supports, changes in seabed topology occurring due to sand waves, erosion or scouring. These free span sections damage the integrity of subsea pipelines and can shorten their life due to loading causing fatigue and.

Traditionally, strakes or fairings have been used in an effort to offset the likelihood and intensity, however, these have proven to be difficult to install on subsea pipelines. They also have durability issues because of moving parts.


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In addition, low seabed clearances and other obstacles can prevent fairings from rotating with changes in flow, rendering them ineffective, while strakes are susceptible to wear and impact damage to their distinctly prominent profile. This is where AMOG turned to the cactus to find the answer — and it has already proved successful in real world operations. After they conducted small scale testing at Monash University to optimise. We were delighted when field test data from offshore installations proved just that. A key requirement of the project was for the pipeline to be fitted with a VIV mitigation device that had a low drag profile due to the prevailing strong currents in the area causing unacceptably large lateral load scenarios.

The project also involved several other challenges, including inconsistent and low clearances with the seabed, large dimensional tolerances and physical features of the pipe, and a year design life. Those traditional methods — such as helical strakes and fairings — cannot always be readily deployed on pipeline free spans due to access and seabed clearance limitations and durability concerns. Interface points on the shroud were designed to have latching and alignment features compatible with VIV strake installation tooling to speed up the design process and increase the technological readiness level of the installation procedure, meaning no major design changes were required.

In addition to the rubber pads, ratcheted fasteners were incorporated into the shroud to allow it to be tightened around the pipe to accommodate pipe sections of varying size.

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In all, Matrix was able to take the job from award to design and full completion in just six months, with the LGS shrouds installed using solely an ROV system that achieved a subsea installation rate of approximately two metres for every 10 minutes. Even when strakes can be installed, their high aspect ratio of fin height compared to base width and overall pipeline diameter can prove to have drawbacks for operators. As a result, oil spill accidents have focused attention on industry and governmental responses to oil spills, and what actions can best prevent them from happening and how best to manage them if they do occur.

Spills may take weeks, months or even years to clean up, so understanding how and where oil is moving through the water column is of critical importance to ensure the process of remediation is both efficient and effective. In a recent offshore exercise conducted by Oil Spill Response Ltd. The OSRL exercise was designed to understand how new remote sensing technologies can help detect and manage oil spills at sea more effectively. Utilising the latest in satellite, airborne and in-water surveillance and communications equipment, the successful event demonstrated the value of the technology in identifying and monitoring spills and was conducted with full approval of the Marine Management Organisation MMO following a rigorous planning and stakeholder consultation process.

A minimal amount of oil was released under carefully controlled conditions and with approval from the MMO.

PipeFlow Software

On hand was the full complement of oil spill response equipment and personnel, including a purpose-equipped vessel, containment and recovery equipment and UK approved dispersant. At the time, Kongsberg also looked at composite, but steel or concrete solutions were the preferred solution as they were proven materials for subsea storage tanks. NOV is introducing composites into its subsea storage prototype designs. The resultant cost savings that this promises could make the underwater storage of hydrocarbons a feasible field development tool.

Inside the tank, a flexible bag was used to obviate the risk of an emulsion layer while the combination of the membrane and steel shell provided a double barrier against oil spill. The internal membrane meant that there was no need to design against seabed pressure. Making production viable, therefore, demands a relatively large hydrocarbon reserve base. Employing subsea storage, however, could not only be a potentially much cheaper and less weather-sensitive alternative but also a safer solution due to not requiring human involvement or helicopter transfer.

The product could be offloaded periodically into a shuttle tanker for onward distribution to market. Subsea storage, however, is not without its history, nor its problems. In the past, oil has been stored in the base of concrete Condeep platforms and within steel storage tanks, however, this has been accompanied by instances of emulsion layer buildup and toxic settlement.

In , Kongsberg began to look at. The original vessel had 25,m3 of storage capacity. To install this vessel, two methods were chosen as a base case. One was to use a conventional vessel installation with subsurface tow out, including external buoyancy tanks and the other, a heavy lift vessel installation with tow out on a barge. This, however, highlighted one of its main drawbacks. Being constructed of steel and concrete made the tank very heavy, and there were not that many vessels in the world that were able to lift it.

This had an impact on installation costs. The seawater outside the structure surrounds the membrane through free-flow seawater openings in the structure, such that the hydrostatic pressure acts directly on the stored fluid. The central pipe assembly is designed for in and outflow of the crude into the membrane. The membrane is filled and emptied from the bottom. Differences in density between crude and seawater creates a horizontal interface where the membrane separates the two fluids.

The membrane continues to move downwards as the storage unit is filled. In , Kongsberg sold the group involved with its development to NOV, about the time that the downturn was about to start. On the back of financial pressure, this encouraged a re-think. By utilising composites as the structural material for the subsea storage unit, thermal insulation, high-strength,. Make no compromise between performance and ease-of-use.

Reducing the unit size, enabled a cluster unit configuration, connecting multiple units together in a frame and providing an even more flexible system. The small-scale testing was conducted together with Equinor. This included verifying filling and offloading cycles of a storage unit and a cluster unit, by confirming consistency in operation. The next and final step of the technology qualification programme includes a large scale verification, as well as some parallel activities. The large-scale verification is planned to start Q3 , and be completed Q3 The large scale verification model will be built in composite, to represent the field version, qualifying the protection structure design and material.

Different protection structure design solutions are also being evaluated. One such design is a single skin wall structure with a thickness of typically mm. Their Cable Monitor tool measures the insulation resistance and continuity of electrical lines. When used in conjunction with the Subsea TDR tool, faults can be localised with a precision of 10cm. Stephen Leung, Subsea Controls Engineer said," We were able to quickly locate and replace the faulty equipment much quicker than traditional testing methods.

With our tools being so small, we can quickly deploy our units to our customers no matter where they are located. This landmark event occurred during an umbilical installation operation off the coast of Australia.

Handbook on Marine Environment Protection | SpringerLink

Subsea TDR unit can localize a fault with an accuracy of 10cm, and the Sensor Monitor can read well-head sensors directly, without a controls package. This year will see MacArtney deliver the next autonomous winch systems for the deployment of synthetic aperture sonar. The custom-built unmanned winch systems are designed to military specification using aluminium alloy for low weight and durability. Providing mechanical design and engineering drawings MacArtney manufactured and tested the Unmanned Winch Systems, and additionally provided the autonomous operation software and control.

Locate faults in sensors before breaking containment. Remove risk to divers and environment from unexpected pressure releases. Safe for use on all subsea infrastructure, giving better data faster. Less than a metre in length and just four kilogrammes in weight, the ecoSUB will enter one of the most hostile environments on the planet to take measurements such as temperature and salinity as far down as metres below Kronebreen glacier on Svalbard.

The work will give researchers a clearer picture of how warming ocean properties affect the calving process. As it rises, it circulates and creates a sandpaper effect against the face of the glacier. This process undermines the wall of ice, causing huge chunks to collapse into the sea. Not only is there a risk of falling ice, but largescale calving causes huge waves, so it is a dangerous environment.

That is where the ecoSUB will come into its own, working at the front line of Arctic science. This water is fresher than the surrounding sea water, so starts to rise in the water.


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The expanded facility in Slangerup. Waterstop Seals provide a solution for isolating a section of flooded annulus in offshore risers or flowlines by preventing water passage to the adjacent Pipe-InPipe sections during installation and normal operation. The contract win demonstrates. The new design addresses potential challenges experienced with High Frequency Welded HFW pipes and seam welded pipes being introduced within the industry as part of cost-saving measures. Subsea Innovation are one of the only suppliers in the world to have successfully tested Waterstop seals with a proven recorded on HFW and seam welded pipes.