Subsea technology - a necessitydoc.mediaplanet.com/all_projects/1961.pdf · SubSea TechnOlOGy 1st....

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Separation technology has increased the wells’ recovery rates, while at the same time availability has also been satisfactory.

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Separators on the seabed

Read more page 4 - 5

Reduced maintenance costs

The key to understanding reservoirs

MAINTENANCE GOES UNDER WATER:

LOWER COSTS, BETTER DECISIONSRead more page 12 Read more page 13

INTEGRATED OPERATIONS:MULTIPHASE METERS:

INNOvATION NORWAy:

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THIS BROCHURE IS AN ADVERTISEMENT FROM MEDIAPLANET

SUBSEA TECHNOLOGY

Field develop-ments based on subsea installa-tions

Subseatechnology- a necessity

Stig Støme of AGR Petrleum Services

1st edition -april 2008

”

” The value may amount to many Hundreds of millions of US$ per annum in

increased recovery from the Norwegian continental shelf, and much more in the rest of the world. Ola Michael Vestavik, General

Manager ReelWell

The Shtokman field on the Russian side is anotherexample of a field that requires both subsea

processing systems and knowledge about long step-outs and about deep water.

adverTisemenT 6 adverTisemenT 6

THIS BROCHURE IS AN ADVERTISEMENT FROM MEDIAPLANET� april 2008

The market forecasts for the subsea and deepwater E&P in-dustry are promising. According to Douglas-Westwood, deepwater oil and gas production in 2011 will be twice the

2006 level. Norwegian subsea history goes way back to the early production system at Ekofisk in 1971, through pioneering tech-nology at Nord-East Frigg and TOGI to the Gullfaks satellites, the enormous Snorre UPA and the compact HOST templates with in-tegrated manifolds.

The need to go deeper and use available infrastructure capacity offshore was a key driver in the early era of the Norwegian subsea industry. Flexible field development and early production build-up were added benefits. Innovative subsea solutions were further boosted by requirements set by Norwegian authorities for diver-free and trawl-protected subsea production systems.

New ground has been covered in just the last couple of years with Aker Kvaerner Subsea’s high pressure/high temperature X-trees at Kristin, ABB/Vetco Gray GE’s Subsea to Beach system with 142

km multiphase pipeline well-stream transfer to shore at the Snøhvit LNG plant, and FMC’s 1000 ton manifolds for Ormen Lange at a water

depth of 900 m, 100 km from shore. Recently the Vigdis Subsea Processing System was installed, adding life to a declining field by boosting oil production and removing produced water.

Looking back, the Norwegian continental shelf has been the ideal arena for developing and testing solutions to meet the challenges, whether it be harsh Atlantic metocean conditions, demanding reservoir management and well completion requirements, or up-scaling dimensions to serve some of the world’s most productive offshore fields. Collaborative business environments and govern-ment programmes to support research, development and demon-stration (e.g. DEMO 2000 and PETROMAKS) are key ingredients in a successful industrial cluster.

The Norwegian subsea industry has been keen to explore this competitive advantage, made possible by the willingness of ope-rators like Statoil, Hydro, Saga Petroleum and international majors

Elf/Total, Shell and ExxonMobil to adopt new technology. For the subsea suppliers and contractors, moving from a demanding home market into a global one was a natural step.

Why subsea? If you have available infrastructure like a tie-in point, processing capacity, water handling and gas offtake, a subsea tie-in will save large capital expenses compared to independent develop-ment, especially in deeper waters where floating production is the only real surface facility option.

However, subsea production technology offers more featu-res to the asset team or field developers – fast-track drilling and production, phased investments, flexible or hub developments to mention a few. The classic field development decision is to ba-lance these benefits against the economics of scale offered by a platform based well cluster with dry trees – water depth and tech-nology limits permitting.

Operators and contractors are now getting used to the idea that oil and gas exploration and development will be pushed into the ultra-deep of 3,000 m and beyond, a cold, wet place where external pres-sures present design challenges. More functions will be located on the seabed or in wells. Subsea processing systems are being ordered for deployment in the deepwater corners of the world. The technolo-gies include separation with sand management, raw seawater injec-tion and multiphase pumping systems. Next out is subsea gas com-pression, with a full-scale pilot at the Ormen Lange onshore plant. Ultra-long tie-back of up to 500 km to shore will make entirely new demands on wellstream conditioning and flow assurance, boosting and energy supply, remote control and intervention.

Maximum recovery will be an important design consideration in new subsea developments. Until now, the toolkit has been limited. Subsea fields of the future will offer a range of functions and equip-ment for well completion control, low-cost well intervention, on-line monitoring. Subsea multi-phase flow meters with fiscal pre-cision will enable completely new field architecture for connecting multiple fields to a gas trunk line across licence boundaries.

Maximumrecoverywillbean im- portantdesignconsiderationinnewsubseadevelopments.

Deep, Distant, Difficult? Or Flexible, Fantastic and Fun…The ever-increasing global energy demand and the need to go further out on the continental shelves to find new likely oil and gas deposits are the two key factors driving the subsea industry to record heights and record depths.

Challenges ”Norwegiansubseahistorygoeswaybackto theearlyproductionsystematEkofiskin1971.

SubSea TechnOlOGy 1st. edition april 2008

Managing Director: Ståle Husby

Chief Editor:Petter T. Stocke-Nicolaisen

Sales manager: theodor sandegrenProduction manager: Bjarne s. BrokkeDesign: tonja ingrid sødal, Henrik ek, Merete askildsen

Project manager: Henrik Brustad sjøliephone: 22 59 30 22e-mail: henrik.sjolie @mediaplanet.com

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programme director, demo 2000, research Council of norway

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The tougher the energy demands,the smarter the solutions.

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StatoilHydro is constantly seeking sustainable solutions to meet future energy needs. In fact, more research and development will go into the production of a barrel of oil tomorrow than a barrel produced yesterday. Our pioneering projects to capture and store carbon emissions put us in the front of supplying tomorrow’s fuel while reducing our impact on the environment. It’s just as well, as the next generation will measure our commitment to the environment by the projects we do today.



norwegian technology:

extraction in ultra-deep water

CATO BrUArøY [email protected]

Extraction in deep and ultra-deep water down to a depth of 3,000 metres is very deman-

ding on the equipment being used. Subsea solutions will represent the only possibility of extracting oil and gas from new finds in many fields. Norway is the world leader in this technology.

”The harsh conditions in the North Sea meant that companies produ-cing on the Norwegian continental shelf had to develop subsea techno-logy early on. The world’s leading

However, the closer you get to rela-tively inaccessible areas such as very deep water or vulnerable environ-ments, the stricter the criteria will be-come concerning the robustness and quality of the equipment,” says Bø.

Deepwater fields present a number of challenges such as high pressure levels and high temperatures. Many new fields are also located far out to sea, and the criteria the technology will have to satisfy will increase as the ”easy” fields are found and come online.

”We have good experience in

dealing with this sort of tough chal-lenges in Norway. High pressure and high temperature world records were set in connection with the Kristin de-velopment. At Ormen Lange the gas is transported 120 km to land, and from the Snøhvit field it is 160 km to land. These fields hold the world re-cords for long step-outs,” says Støme of AGR.

Government stimulating research There are several reasons why Nor-way has become the world leader in subsea technology. The fact that

and knowledge about long step-outs and about deep water,” says Støme.

Quality criteria As mentioned, sub-sea technology is very suitable for the development of ultra-deep water sites. The technology also represents a way of reducing the need for sur-face platforms. According to Total E&P Norge’s Director for Operations and Projects, Tore Bø, subsea tech-nology results in large costs savings. Great progress is still being made in research.

”In order for subsea technology to meet the needs of tomorrow, it is important that as much of the ne-cessary processing as possible takes place on the seabed – preferably combined with down-hole techno-logy. Comprehensive, wide-ranging research is currently taking place in Norway. Projects are taking place in the supplier industry involving both subsea construction and down-hole technology (separation and flow enhancement). Some are already in operation. One example is the Tor-dis field in which StatoilHydro uses subsea separation, sand filling and water readjusting. This technology is starting to come online, but there are some challenges which mean it can-not be fully utilised yet,” says Bø.

He believes that the equipment will have to meet even stricter quality cri-teria in the future.

”Quality is very good today.

concentration of experts has been established in the Oslo area. Foreign experts are attracted to this area, and companies from other parts of the world come to Norway to get help with developing fields in deep wa-ter,” says Støme.

Centre of excellence Støme is the sec-tion manager for subsea solutions at AGR and has over the last year built up a team in Oslo that can deliver everything from early phase scree-ning to project management in turn-key and tie-back projects throughout the world. His competitors are right next door.

”A subsea cluster has been estab-lished in Norway with a high level of competence which is transferred to other geographic regions. I have myself participated in the develop-ment of a field in Angola that was at a depth of 1,500 metres. At the moment there is an ongoing major subsea project in which the instal-lation will take place in India, while the head office is in Norway. The Stockman field on the Russian side is another example of a field that requi-res both subsea processing systems

”Future oil fields will be increasingly inaccessible to conventional techno-logy. The developments within subsea techno-logy are the answer to these challenges,” says Stig Støme of AGR Pet-roleum Services.

TOre Bø, direcTOr fOr OPeraTiOns and PrOjecTs fmc TecHnOLOgies., TOTaL e&P nOrge

Inorderforsubseatechnologytomeettheneedsoftomorrow,itisimportantthatasmuchoftheneces-saryprocessingaspossibletakesplaceontheseabed–preferablycombinedwithdown-holetechnology.”

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stig støme section Manager for subsea solutions at aGr petroleum services and Gunnar Øslie, project Manager at aker solutions


Pumping up service life

LASSE BErGESEN [email protected]

Oil companies are unable to extract more than 40% to 50% of the oil in a reservoir

without the help of aids. The reason for this is that the pressure in a well falls as the oil is extracted. Over time the pressure drops to such a low lev-el that the oil no longer flows up to the oil platform unaided.

Water injection and multiphase pumps are common methods of increasing recovery factors. The pumps pump the oil to the surface while water injection helps to main-tain the pressure level in the reser-voir, meaning the oil continues to be forced out.

”Calculations carried out by us and others show that it is possible to increase the recovery factor to 50-60%. Locating the pump instal-lation on the seabed results in much greater efficiency, and an energy saving solution, than operating a platform on the surface does, and at the same time one extracts more oil,” says Tom-Erik Dahl, Business Development Manager, Processing and Boosting at Aker Solutions.

Subsea installations result in ma-jor benefits both when using water injection and when oil is going to be separated from water.

”With water injection you can locate the pump near to where the water is going to be injected. With separation the oil can be separated on the seabed and the water can be

injected directly into the reservoir, with only the oil being pumped to the surface. In both cases one saves energy because one avoids having to pump water up to the surface and then down again. Placing the pump on the seabed is also practi-cal because space on a platform is often limited,” says Dahl.

One of the fields Aker Solu-tions has installed its MultiBooster technology in is BP’s King field in the Gulf of Mexico. BP wants to increase the recovery factor from the field by 7% and extend its service life by five years.

”One has to install such solu-tions in new fields at the start. Many fields would not be put into production without such technol-ogy,” says Dahl.

extraction on the Norwegian conti-nental shelf is demanding has been a crucial factor. However, the fact that the Norwegian authorities have facilitated research and development within subsea has also been impor-tant.

”Norwegian legislation is stricter than in the rest of Europe. The Swe-dish authorities want, for example, oil extraction to take place pursuant to Norwegian regulations rather than the EU’s regulations. One important reason why Norway has strict rules is that we have much greater producti-

on from the wells than in many other places. With high production levels a high level of accessibility is profita-ble, and quality results in a high level of accessibility. The increased costs of such strict requirements are more than balanced by high revenues,” says Støme.

Bø of Total EP Norge also believes that the Norwegian tax system has contributed to the country’s techno-logical progress.

”The tax system is structured in a way that stimulates research. This is a very deliberate policy on the Norwe-

gian side, and is a basic prerequisite that has allowed Norway to achieve the position it currently holds within offshore technology,” says Bø.

He also points to the importance of the good general conditions for R&D not being undermined.

”If research in subsea technology in Norway continues at the same high tempo in the future, it is impor-tant that the general conditions be sustained. It is risky to believe that one can coast along on past achie-vements. Research is a continuous process,” says Bø.

Pump installations on the seabed can increase the recovery factor for oil and gas fields by up to 20%. Norwegian developed technology is helping to in-crease the service lives of oil fields by many years.

subsea installations result in major ben-efits both when using water injection and when oil is going to be separated from water, says tom-erik dahl, Business development Manager, processing and Boosting at aker solutions.

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PHOTO: KrisTin Lyseggen


...technologymakesthedrillingprog-ressindependentofgravity.”

pHoto: anne lise norHeiM


Horizontal drilling over longer distances is difficult and ex-pensive. Many wells often

have to be drilled in order to recover oil deposits from a defined area. Reel-Well is now developing new technol-ogy that makes it possible to drill hor-izontal wells over more than 20 km.

”The expression ’horizontal drill-

ing’ is used for wells that are drilled at almost a 90 degree angle in re-lation to the Earth’s gravitational force. Normal drilling uses the gravi-tational force on the well casing to progress and to apply force to the drill crown. When one is going to drill long horizontal wells the fact that gravity is not pushing the well casing in the direction we are drilling in is a problem. This results in limited range,” says Ola Michael Vestavik, General Manager of ReelWell.

The Norwegian oil technology company ReelWell has developed a new method that enables horizontal drilling over long distances under the seabed. This results in increased extraction, better profitability and major environmental benefits.

beating gravityThe company’s technology makes

the drilling progress independent of gravity. The force is applied hydrau-lically using a piston that pumps it forwards from the surface. This hy-draulic force works just as well in a horizontal as a vertical direction, and means that the horizontal drill-ing range is considerably increased. Such drilling will also be able to take place from lighter drilling facilities.

Designed for normal drilling equip-ment ”We have developed and pat-ented new methods and equipment components designed for normal drilling equipment, meaning we can drill wells in any direction regard-less of gravitational force. The tech-nology also improves well cleaning because of a new, patented principle

similar to using a vacuum cleaner. The technology contributes to bet-ter control of the pressure in the well during drilling operations. This re-sults in significantly improved safety in some situations,” says Vestavik.

He points out that the technology also makes it possible to increase ex-traction from a field due to improved drainage. More oil can thus be ex-tracted than would otherwise be pos-sible with the same investment costs in wells and infrastructure.

Major value creation According to Vestavik the recovery factor can be increased significantly. By how much is a question of costs and the prices for the oil/gas that is extract-ed. Vestavik points out that the value will be especially large in fields with

seabed wells due to the generally low level of extraction here.

He believes the technology could result in potential cost savings of around 50% in relation to traditional technology, especially when lighter drilling facilities from ships are used. The cost savings come from using smaller, cheaper vessels, smaller crews, quicker operations and low costs for fluids and materials, etc.

”The value may amount to many thousands of millions of NOK per year in increased extraction on the Norwegian continental shelf, and much more in the rest of the world. The technology could thus also help to make non-profitable finds profita-ble after all, because of the improved drainage as well as cost reductions,” says Vestavik.

new technology makes it possible to drill at almost 90 degrees angle in relation to the earth’s gravitational force


especially adapted technologies are working to reduce costs while avoiding environmental strains to the delicate arctic regions.

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”In Arctic regions the equip-ment is exposed to wind and weather in a way other than

what we are used to. It therefore has to withstand more cold and adverse conditions. In areas with permafrost, heated pipelines could result in un-stable pipeline routes, and pipelines and subsea installations in vulner-able areas will have to be recessed into the seabed to avoid damage from drifting icebergs,” says Profes-sor Sigbjørn Sangesland at the Nor-wegian University of Science and Technology, NTNU.

Challenges lining up Seismic surveys will be very difficult and expensive to conduct in ice-covered regions. Great distances to land and the lack

of infrastructure entail technical flow challenges associated with multi-phase transport and wax and hydrate formation in the subsea system.

”Helicopters have to fly over great distances, and without refuelling opportunities this type of transport will be a challenge. Given the great distances one can envisage the local processing of well flows in large per-manent vessels before shipping on or the processing of well flows taking place on the seabed or in the actual well hole. Pumping and compres-sor stations with significant power needs will thus become a necessity in the event of pipeline transport over great distances,” says Sangesland.

When operating in areas with a

The search for and the production of oil and gas deposits in Arctic regions are presenting new and tougher challenges. The harsh climate means equipment and systems have to meet stricter criteria than they do when searching for and producing under normal climatic conditions.

arctic challenges

lot of ice one has a narrower weather window to work with for well drill-ing, the installation of seabed equip-ment and maintenance. Using large vessels, possibly with the assistance of icebreakers to deal with ice floes and thus expand the weather win-dow, is a potential solution.

”In such situations one has to use equipment and systems that enable quick connection and disconnection from seabed installations and the movement of vessels if critical situ-ations occur. There will be a need to develop better systems for monitor-ing ice floes and icebergs. By moni-toring the direction of drift one can steer away, blast away or influence the direction of drift of icebergs at

an early point to avoid collisions and damage,” says Sangesland.

Zero discharges are a requirement in Arctic regions. This means, for ex-ample, that drilling cuttings must either be re-injected or transported to land for cleaning and disposal.

Subsea installations are control-led hydraulically and hydraulic oil is normally dumped in the sea-bed near the subsea installation or transported back to the starting point. The latter is expensive and results in operational limitations if this involves great distances.

”Introducing wholly electrical control systems, which are cur-rently under development, avoids

polluting the surroundings. This ensures safety and systems in-tegrity, and minimises the danger of unnecessary discharges,” says Sangesland.

Another technology currently under development is drilling thin-ner holes with a uniform diameter from top to bottom.

”Drilling a smaller hole reduces the drilling materials significantly. There is less drilling fluid, less ce-ment and less steel. This also enables the use of cheaper and smaller rigs for this type of operation. This will result in less consumption of every-thing and result in simpler logistics and lower emissions of climate gas-ses,” concludes Sangesland.

”Helicoptershaveto fly over great dis-tances, and withoutrefuelling opportuni-tiesthistypeoftrans-portwillbeachallenge

sigBjørn sangesLand, PrOfessOr,THe nOrwegian UniversiTy Of

science and TecHnOLOgy, nTnU.


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THIS BROCHURE IS AN ADVERTISEMENT FROM MEDIAPLANET10 april 2008

erLend fjøsna, Head Of sUBsea PrOcessing,

fmc TecHnOLOgies.

Thesectorhasrea-chedastageinwhichmethodology andcompetence meanthat one can movenewandbettersubseaprocessingtechnologyforwardtogetherwithclients in a safe andcontrolledmanner.

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Subsea separation - a new era

HELGE MiLdE [email protected]

The Tordis IOR project real-ises the first commercial full-scale subsea separa-

tion installation in the world. Separating out water and sand

Hydro’s Troll C Subsea Sepa-ration was the world’s first subsea separation instal-

lation. The solution was named the engineering feat of the year in Nor-way in 2002. The subsea separator installed in 1999 was developed in partnership with ABB Offshore Sys-tems, now called GE VetcoGray.

Separation technology has in-creased the recovery factor for wells, while at the same time avail-ability has been satisfactory. The

have visited Norway to view the project. Tordis has without ques-tion opened up the market for sub-sea processing opportunities.

”Total, the oil company, is bas-ing the development of its licence for the Pazflor field off the coast of Angola on gas fluid separation. The development of this technol-ogy is a continuation of the expe-rience from the Tordis IOR project, among others. The awarding of this contract to FMC is yet fur-ther recognition that our ability to qualify new technology is highly appreciated out in the market,” concludes Erlend Fjøsna.

it all started in 1999...

ney to Gullfaks C at sea level. This saves energy while also reducing the discharge of production water into the sea.

Separating oil from water is normally performed topside or onshore. Locating the system sub-sea therefore brought topside and subsea expertise together, mean-ing that two different approaches needed to merge. As a symbol of bringing the two cultures togeth-er the topside tradition of naming a ”platform” was taken subsea.

TIORa was named by Margareth Øvrum, VP Statoil. Start-up oc-curred in late December 2007. To-day, following a period of tuning, calibration and minor changes, the system is now operational.

Remote Control and monitoring The system control unit is located topside on the Gullfaks C platform, along with two hydraulic pow-er units - one for barrier fluid to the pumps, the other for the con-trol system. Power to the pumps is controlled by the two variable speed drives. Extended process-ing control and status monitoring is included. Tordis IOR sets a new standard vis-à-vis control con-cepts for subsea processing sys-tems.

Massive interest The interest in FMC’s project has been tremen-dous. All the major oil companies

on the seabed and injecting this waste into a dump reservoir in a closed loop system represents an environmental technology for the future. StatoilHydro expects to improve the Tordis field’s recov-ery factor from 49% to 55% and to extract 35 million barrels of additional oil from the field.

”The sector has reached a stage in which methodology and com-petence mean that one can move new and better subsea processing technology forward together with clients in a safe and controlled manner. The technology in the Tordis IOR project has demon-strated its reliability,” says Erlend Fjøsna, head of Subsea Process-ing at FMC Technologies.

Simply put: the more water in-jected - the more oil recovered. The ”simple water injection sys-tem” was, however, modified to offer more functionality than was first intended. Specifically, this involved the engineering and fabrication of a more advanced protection structure and qualifi-cation of the new water injection tree with the wellhead system.

Saves energy The separated water and sand are pumped down into the Utsira formation directly from the subsea installation and stored there. This solution means that large amounts of water from the reservoir avoid the 10 km jour-

For years engineers have dreamed of sepa-rating oil from water and sand on the seabed. Today, with the Tordis IOR project in the North Sea, StatoilHydro, FMC Technologies and their partners have made this dream a reality.

the tordis subsea processing system on its way to the seabed.

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fibre rope deployment system

it all started in 1999...

ÅSMUNd PEdErSEN [email protected]

”Both vessels and deploy-ment systems have to be larger to cope with

the steel wire’s own weight and that of the subsea module. This results in a significant increase in relation to both costs and environmental pollu-tion,” says Per Ingeberg, President of ODIM Alitec.

A system that compensates for the movement of the vessel in relation to the module being deployed may be needed to ensure the subsea module lands safely on the seabed.

”This is one of the challenges the deployment system must overcome in a very precise and effective man-ner. Greater weight increases the need for power supply from the ves-sel and presents greater challenges in relation to precision. Fibre rope based deployment solutions are currently the best alternative,” says Ingeberg.

Fibre rope It is particularly impor-tant that the right deployment sys-tem is used when using fibre rope. Fibre rope is less resistant to heating caused by the friction between the rope and the deployment system.

”Fibre rope is a more elastic ma-terial than steel wire and will stretch by different amounts with variable loads. You therefore need to use a deployment system that automati-cally compensates for this. A great deal of attention must be paid to this so that the industry does not choose solutions based on price, but instead stipulates stricter criteria concerning the verification of the technology,” says Ingeberg.

Better understanding The challenges must be resolved through a thorough understanding of the material prop-erties of fibre rope and how the laws of physics act during deployment.

”Modelling and simulation of the rope through the deployment sys-tem, the design of torque controlled sheave wheels based on the friction coefficient between the sheave wheel and the fibre rope, an understanding of the fatigue factors, and the ability to measure changes from a starting point, are only some of the compe-tence one must have in order to de-sign a relevant deployment system for fibre rope,” says Ingeberg.

Using fibre rope instead of steel wire to submerse installations to depths below 2,000 m results in both costs and environ-mental benefits.

Norwegian subsea sector is con-vinced that subsea separation will spread in the future, and several companies are working on improv-ing the technology.

”One important aspect is when wells have passed their peak pro-duction. After this the proportion of water in the oil will naturally in-crease. This consequently affects the volume being transported and the costs per expanded unit of oil if one does not employ seabed separation.

Both Troll and Tordis are examples of this,” says Fredrik Witting, Sales Director at VetcoGray. The solution is also relevant for fields located in deep water, if great distances are in-volved, and in areas without infra-structure.

The fact that Norway is the world leader in its development is primarily due to the open part-nership climate that characterises Norway when it comes to research and development. Oil companies,

the supplier industry, and research institutions work together closely in order to stay at the forefront of technological development. This provides Norwegian operators with a major competitive advantage in the fight for new licences through-out the world.

”This is pretty unique to Norway. However, the close cooperation re-sults in a very dynamic and competi-tive supplier industry internation-ally,” believes Witting.

new technology makes it possible to submerse subsea modules to extreme depths.

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Research for the future

Maintenance goes under waterThe Riserless Light Well Intervention Technology provides access to subsea wells and increases oil production.

HELGE MiLdE [email protected]

Reducing the cost of main-tenance is the principle driving force behind the

development of the Light Well Intervention (LWI) technology, together with increased oil recov-ery from the wells. With increased access for only one-third of the cost of a typical intervention, oil companies can better monitor and gather more information from the reservoirs worldwide.

”The feedback from exist-ing customers is very good. They have shown that Light Well Inter-

vention using monohull vessels instead of floating rigs is an im-portant tool when it comes to im-proving knowledge about the well before implementing larger meas-ures in the next phase, which in-crease production. Access to rigs is difficult when drilling operations take priority and the day rates for rigs have shot up. Leasing a float-ing rig in the North Sea can easily cost up to USD 500,000 per day. In addition to this come the costs of using the equipment and systems, says Ingmar Nyheim, Director of Sales & Business Development at FMC Technologies.

Well maintenance can be per-

formed using Dynamically Posi-tioned (DP) vessels instead of large anchored drilling rigs resulting in shorter times and lower costs. The Riserless Light Well Intervention (RLWI) technology includes a pat-ented lubricator system with the recirculation of hydrocarbons into the well. The system is deployed through a moonpool from a dy-namically positioned vessel, and is installed on the subsea Christ-mas tree without using anchors or risers. Nyheim sees several rea-sons why this technology will be important in the future:

”The future for well intervention is good because of at least two fac-tors: the operator’s maintenance costs are reduced and, by no means least, the measures taken with re-spect to the well result in oppor-tunities for increased production. This is not only important from the point of view of operators, it is also important from a national perspective because optimum use is made of the resources against a background of a trend of reduced

oil production in Norway.” According to StatoilHydro’

estimates, Riserless Light Well Intervention technology and other technologies could increase potential recovery by one bil-lion barrels of oil off the coast of Norway. According to statistics from the Norwegian Petroleum Directorate (NPD) conventional

subsea wells extract 8% less oil than regular sea wells. The inten-tion of the RLWI technology is to equalize this gap, representing an increase of USD 30 billion in Norway’s oil recovery over a ten-year period. Increased oil recov-ery and revenue are not limited to Norway but can be achieved worldwide.

ingmar nyheim, director of sales & Business develop-ment at FMC technologies.

Maintenance may require larger vessels than a roV. a dynamically positioned (dp) vessel may be a good solution.

iLL: viscO

THIS BROCHURE IS AN ADVERTISEMENT FROM MEDIAPLANET 1�april 2008

Hans OLav Hide, managing direcTOr, mPm

”

T H E D E E P W A T E RS U B S E A S E R V I C E S

P R O V I D E R

DeepOcean`s business is:

IRM, Survey andConstruction SupportUsing modern DP2 vessels, state of the art ROV’s and subsea equipment and a personnel resource group of very experien-ced people, DeepOcean has moved fast to be one of the growing internationalsubsea service providers assisting both oilcompanies and the major contractorsworldwide.

Seabed mapping /Survey and PositioningDeepOcean operates complete spreads forHydrographic Mapping Surveys, Geotechni-cal Surveys, Route and Site Surveys including vessel and ROV–mounted multi-beam echosounders for various depths anddata quality. Our expertise and experienceenables us to perform high quality surveysin all water depths worldwide.

Pipeline InspectionsDeepOcean operates a modern fleet ofSurvey ROV’s and equipment especiallydeveloped for safe and cost-effective pipeline inspection work. Furthermore,DeepOcean has a large number of employ-ees with long experience in the branch andhave tailor-made procedures and softwaresystems for work of this type.

Subsea ConstructionSupportDeepOcean’s portfolio of highly specializedvessels, dedicated equipment and skilledpersonnel makes the company an attractivepartner for sub sea construction support.This niche of the industry is important to us.We see ourselves as a global provider of specialized services to major constructioncontractors.

TrenchingThrough its subsidiary CTC Marine Projects,DeepOcean is the world’s leading indepen-dent marine trenching contractor, operatingin the subsea oil & gas, telecommunications,military and utilities sectors of the offshoreconstruction industry. CTC owns and operates the largest, most comprehensiveand technically advanced fleet of trenchingequipment in the world and provides a keycomponent of the international subsea construction market.

DeepOcean ASA - Stoltenberggaten 1 - Postboks 2144 PostterminalenN-5504 Haugesund NORWAY

Telephone: (+47) 52 70 04 00 - Telefax: (+47) 52 70 04 01E-mail: [email protected] - www.deepocean.no

ST

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EN

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Simplified field developmentMultiphase meters add value through lower costs and better output, and can help enable the development of small fields whose development might otherwise not be economically viable.


Multiphase meters meas-ure the quantities of oil, water and gas flowing

simultaneously inside a pipe. The meter is used at the wellhead of oil and gas wells, and the information is used to optimise production and recovery from the reservoir, and recently, to split revenue between partners and the owners of a field.

”MPM Meters help enable sim-plified field development solu-tions, which is of particular in-terest as the era of bigger fields has passed. The Morvin field off Norway is a typical example of a

small oil reservoir being devel-oped and tied back to an existing production facility. Complicated ownership structures and sales of licenses further emphasise the need for metering solutions ac-curate enough to be used for al-locating revenue between differ-ent owners,” says Mr. Hans Olav Hide, managing director of the Stavanger based company MPM.

According to Hide, multiphase meters are the key to understand-ing what is going on in the reser-voir. The information is used by the reservoir and petroleum engi-neers to enhance production from particular wells, and the reservoir as a whole.

”Without this kind of informa-tion, it’s like driving a car in the dark without lights. When these

meters are implemented in an ap-propriate way, the increased rev-enue is many, many times higher than the cost of the equipment. They can also contribute to ena-bling the development of small fields, whose development might otherwise not be economically viable, says Hide.

MPM was recently awarded two contracts to deliver subsea meters, which represents an in-ternational breakthrough for the company’s products.

Multiphase metering is now considered more mature, and most oil companies have started using them. According to the Nor-wegian company Roxar, which has installed more than 300 sub-sea multiphase and wetgas me-ters in challenging subsea fields, the added value from using mul-tiphase meters is low investment costs, less maintenance expense, smaller production loss during well testing and better output maximisation. The elimination of test lines and subsea test mani-folds will further reduce invest-ment costs in relation to subsea developments.

MPMMetershelpenable simplified fielddevelopment solutions,which is of particularinterest as the era ofbiggerfieldshaspassed.

a multiphase meter measures the quantities of oil, gas and water flowing simultaneously inside a pipe.


For further information, please contact Helge tel. (+47) 35 96 81 52 or (+47) 909 45 806. Application with CV to: [email protected]

Idea Engineeringare searching for Structural Engineerswith relevant education as MSc or equivalent.

Idea Engineering AS is supplying engineering services to the oil & gas industry as well as landbased industry.

We can offer:Interesting work tasks in stimulating work environment. Competitive terms and conditions with good pension scheme.

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Weekly newsdistribution to 30.000 business leaders within maritime, oil&gas, offshore and shipping.

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Operations in oil and gas fields can be optimised by using information and

communications technology in near real-time. Large amounts of data from the fields can be collect-ed, distributed and shared between users. Experts who previously had to be transported offshore can thus now do the same job onshore, al-lowing these specialists to contrib-ute their expertise regardless of where they are in the world.

This way of working could result in major costs savings, as well as better quality in decision-making processes, increased extraction and more effi-cient production. Calculations by the Norwegian Oil Industry Association show that on the Norwegian conti-nental shelf alone the value created could amount to NOK 300,000 mil-lion in the next ten years.

Leading Norwegian clusters The Norwegian clusters are far ahead when it comes to working like this.

”There are good examples of the successful use of integrated opera-tions in many parts of the world. For example, onshore facilities in the USA have come a long way, but nowhere have these been rolled out as widely

as they have in the North Sea. There is a correlation between good infra-structure with fibre optic networks and a high level of use of modern IT systems on Norwegian platforms. In addition, some of the operators in the North Sea are very interested in test-ing new technology,” says Håvard Moe, Manager Enhanced Operations & Production of ABB Norge.

ABB’s Norwegian organisation has used integrated operations since the start of the millennium to support fields in operation, both on the Norwegian continen-tal shelf and internationally.

”The oil companies’ motivation for adopting these systems were the op-erational challenges in the offshore fields which needed to be resolved ur-gently. The oil companies simply did not have time to wait for our experts to travel from the office to the heliport and then out to the field,” says Moe.

Over time services have become standardised and formalised with agreed response times vis-à-vis making expert assistance availa-ble. The service was also expanded to cover monitoring facilities.

”This expansion means that ABB not only resolves operational problems, it also suggests meas-ures for improving production efficiency when the facilities are producing as normal. The service

Integrated operations mean much more ef-ficient cooperation and information sharing, and can result in substantial value creation from oil and gas fields.

Integrated efficiency improvements

is currently delivered to a number of oil companies either by us con-necting to them using secure sys-tems from our offices or by our experts working with the facilities from secure rooms at the oil com-panies’,” says Moe.

Increased value creation Egil Birkemoe, Sales Manager En-hanced Operations and Produc-tion at ABB, points out oil fields

that require close follow-up from experts are especially well-suited to integrated operations.

”Fields in their start-up phase and fields in tail production of-ten require extra follow-up. These are clear candidates for integrated operations. These will typically be fields in which the operating con-ditions have changed, meaning the field ought to be closely fol-lowed up by competent personnel.

The fields should also be of a cer-tain size to justify the investment in technology,” says Birkemoe.

He stresses that the organisation must be focused, innovative and willing to change for integrated operations to be successful.

”The aim is to enable better and faster decisions. The correct use of integrated operations increases the value created by oil and gas fields,” says Birkemoe.

Håvard Moe, Manager enhanced operations & production of aBB norge.

integrated operations are allowing process data to be efficiently shared between users.

PHOTO: aBB

iLL: viscO


Innovation on the oil and gas frontier

Government funding provided through Innovation Norway ensures interdiscipli-nary activities in the oil and gas sector work at full thrust, among other things through the renowned ARENA projects and Norwegian Centres of Expertise (NCE). ”Ingenious clustering ensures state-of-the-art solutions for the oil and gas industry,” says Trond Olsen, General Manager, NCE Subsea.

Request additional informationInnovation Norway, the Industrial Development Corporation of Norway(SIVA), and the Research Council of Norway are all representatives of the government’s investment in the clusters. Should you have further ques-tions please do not hesitate to contact us directly - we value close contact with our market. Head of Sector for Oil & Gas at Innovation Norway: [email protected]

Long-term innovation activitiesSince the late seventies, the Nor-wegian Continental Shelf (NCS)

has almost functioned as an incubator for the development of oil and gas technol-ogy. We now see Norwegian technology originally designed for use on the NCS being used in oil and gas fields on all con-tinents.

The Norwegian government has a tra-dition of supporting oil and gas related technology and business development through numerous programs. Since the start of the new millennium the focus has been on development within strong regional clusters. Today, we experience an increasing cooperation between clusters.

Potent clustering "Strong clusters have arisen along the south and west coast of Norway. Some of these clus-ters are part of national programmes that aim to produce more potent com-munities, outstanding technology and primary services. The projects are fa-cilitators within the clusters. Effective alliances have been established bet-

ween industrial players, R&D institu-tions, schools and authorities, driving innovation and development forward. I believe that government funding is a key driver when it comes to explai-ning why this cluster is on the frontier of innovation," says Kjell O. Johan-nessen, Managing Director of Arena Node.

Norwegian Center of Expertise SUBSEASince the early eighties the sub-

sea industry in the Bergen area, Nor-way, has grown to become one of the world’s most complete environments for subsea technology. The regional cluster is home to more than one hun-dred companies and organisations for which subsea is their only or main bu-siness area. NCE Subsea is an initiative by the sub-sea industry in the Bergen area for the strengthening and internationalisation of business, R&D and education. The cluster’s main focus is on maintenance, modification and operation of subsea installations. NCE Subsea aims to contribute to research, innovation, competence de-velopment and international business development with an emphasis on sti-mulating cooperation and sharing expe-rience within the cluster, and with natio-nal and international partners.

Contact: Trond Olsen, General Mana-ger, [email protected], +47 48 10 88 64, www.ncesubsea.no

ARENA Centre for Smart and Safe WellsThe Centre for Smart and Safe

Wells prioritises the key challenges operating companies face in next gen-eration production. Technology and in-novation are ensured through an estab-lished network, which includes industry, universities, and capital. The focus of attention these days are:

Better management of reservoirs with sophisticated wells for optimal exploita-tion and utilisation. Developing instrumentation for monitor-ing continuous production and condi-tion supervision.

Contact: Trygve Gjerstad, Project Coor-dinator, [email protected], +47 91 75 99 90

ARENA IO, Integrated Operations in the Petroleum IndustryProject Arena Integrated Oper-

ations aim at establishing an environ-ment of expansion making the cluster world leader within this area. Main ambition for the project is to stimulate added value for the petroleum sector in addition to increased profitability and competitiveness for participants in the cluster, through closer collabo-ration, enhanced innovation and inter-nationalization.To reach our goals the project will pursue networking and expansion of technology and expertise, through implementation of joint industrial projects.

Smart real-time operations for the Oil & Gas sectorCondition based monitoring – the way ahead

Contact: Martin Sigmundstad, Project Manager, [email protected], + 47 40 64 60 10, www.arenaio.no

ARENA NODE, Norwegian Off-shore & Drilling EngineeringPioneers since the adventure on

the Norwegian Continental Shelf started in 1972. First established as Oil Industry Services, the first networking organisa-tion in this industry, and today the world's leading supplier of advanced technology, specialising in:

Drilling (approx. 93% of world market) Mooring Advanced Production and loa-ding (approx. 90% of world market)Cranes: Active Heave Compensated Cranes (approx. 73% of world market)

Contact: Kjell O. Johannessen, Procect Manager, [email protected], +47 90 99 08 08, www.nodeproject.no



ClampOn SandQMonitor

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The world’s first and only Quantifying sandmonitor is supplied by the leader in topside

and subsea sand monitoring – ClampOn.

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www.clampon.com

TOM AMriATi-LøvÅS [email protected]

”StatoilHydro has de-fined Automated Drilling Systems

(ADS) as one of our main fo-

cus areas,” says Steinar Strøm, Project Manager at IOR RDW.

”We are working on develop-ing systems that are intended to assist the driller and in some cases override the driller. Us-ing such systems allows you to potentially eliminate many of

the human errors that can eas-ily occur when all of the work in a challenging drilling process is done manually,” he says.

”In the long-term we envis-age a considerably more auto-mated drilling process with the driller performing a supervisory

function,” he explains. ”At the centre of such a system will be a DCDA (Drilling Control and Data Acquisition) system, which will have a number of open in-terfaces with future automated subsystems.”

”One example of an automated

subsystem is Drilltronics, which ensures the monitoring and con-trol of the entire drilling process in real-time,” he says.

”The system is based on com-puter models that continuously process and analyse limits and parameters. The monitoring

leading technologyThe challenges of securing increased capacity utilisation and minimising downtime have been a subject of discussion for many years. Many people now believe that the imple-mentation of automated processes can help to meet these challenges, and in the long-term provide synergies in the form of more economic crew use and safer drilling processes.

real-time monitoring of the drillhole makes it easier to control pressure and reduces the risk for errors.


Sigmatech AS, based in Bergen - Norway, supplies contract personnel to the oil industry world wide.

Our objective is to provide services of high quality and with a high level of safety in order to optimise safety, environmental protection, customer satisfaction and

fi nancial results throughout each project.

If you are looking for personnel within the categories: Shift Supervisor, G5 Crane operator, Rigger foreman or Rigger we can tailor a team to suit your

requirements for offshore and onshore assignments.

Sigmatech AS is qualifi ed in the Achilles Joint Qualifi cation System (nr 25932).

Contact details:Phone: + 47 464 24 000

E-mail: [email protected]

includes the analysis of pro-gression, pump speeds, drilling speeds and optimum processing parameters,” explains Strøm.

”The system for real-time mon-itoring of the drill hole means the response time is significantly reduced,” points out Strøm. In

practice this means that a poten-tial problem at the bottom of the hole will be discovered before it actually becomes a problem and corrective actions can be started immediately. On the other hand, when a person (driller) discovers a problem in a well it is often too

late to take the right corrective measures.

”This is especially true when it comes to managing the pressure at the bottom of the hole. We can control the pressure much more actively with an automated sys-tem than with manual methods.

leading technology

This is, not least, an important pa-rameter when it comes to depleted fields with marked pressure varia-tions between different zones. Tra-ditionally one uses drilling mud with a defined specific weight and manual adjustment of the drilling mud’s specific weight. With real-time control we can, for example, use a choke valve to continuously regulate the pressure at the bottom of the hole. This sort of system will be important in the future, espe-cially in the deep fields in the Gulf of Mexico,” points out Strøm. “In practice this means a marked in-crease in recovery factors, time saved because fewer liners have to be installed, significantly reduced downtime, and possibly less need for different drilling mud systems, which is important vis-à-vis lo-gistics and the environment,” he says.

Economic potential ”The aver-age downtime figure is currently 20%, a figure that is pretty rep-resentative for all players in the sector,” says Strøm.

”With total investment amounting to NOK 50,000 mil-lion per annum, this means that one could potentially save around NOK 10,000 million per

Statoilhydro

StatoilHydro is an international,integratedenergycompanybasedinNorway.Itistheleadingopera-torontheNorwegiancontinentalshelfandisexperiencingaphaseofinternational expansion. Statoil-Hydroisalsofocusingstronglyonthedevelopmentofnewenergy.

With total production equal to NOK 50,000 million per annum, we could potentially recoup NOK 10,000 million per annum just by reducing downtime.

sTeinar sTrøm, PrOjecT manager iOr.

annum just in StatoilHydro by simply eliminating the downtime in drilling and well operations,” emphasises Strøm.

”This technology is still at an early stage. Many of the rigs are designed for automated systems, but we have not taken advantage of this yet. Drilltronics was test-ed on Statfjord C in active mode in January this year, and the re-sults were positive. A telemetry drill stem with a communica-tions cable inside the pipe pro-vides a ’transmission route’ for real-time data from the well dur-ing drilling. This data can be ac-tively used by support software to make the operation more effi-cient overall. Work is also being done on peripheral support sys-tems such as continuously meas-uring and monitoring fluid pa-rameters, automated well casing history, etc. We envisage Statoil-Hydro being able to extract sig-nificant synergies and efficiency benefits from using these types of solutions. In the long-term we envisage remote controlled drill-ing systems.”

”Nonetheless, I would stress that a remote controlled (i.e. no operative personnel onboard) drilling rig will probably not be available within the time horizon of our R&D programme which has been set at 2020,” says Strøm.

”Views differ about what the future will be with respect to the remote control of drilling facili-ties and rigs. We are primarily working on automating the proc-ess to increase operational effi-ciency, improve safety, and elimi-nate human errors,” he points out.

Essential development ”One of the most important factors when it comes to succeeding with an automated system is the develop-ment of telemetric pipes,” stresses Strøm. ”This is the actual nerve fibre of the system and all the data from the bottom of the hole to the various interfaces depends on this data transmission column functioning optimally.”

steinar strØMprojeCk ManaGer, ior rdw

Weareworkingondevelopingsystemsthat are intended toassistthedrillerandinsome cases overridethedriller.

”

PHOTO: øyvind Hagen/sTaTOiLHydrO


Inside ”Despiteinterestingestimates,therearestill manychallenges...

Integrated operationsLarge areas of the Norwegian continental shelf are 'past peak production' with the consequent declining level of activities. A continued high level of activity for the Norwegian supplier indu-stry will therefore require increased international activity.

The Barents region represents good op-portunities for the Norwegian supplier industry, but at the same time requires

increased innovation and technological de-velopment with a particular focus on sustain-able, environmentally friendly, technological solutions. At the same time, measures have to be taken to realise the remaining value on the Norwegian continental shelf (resource utilisation, oil extraction and tail produc-tion). Integrated operations (IO) are being de-veloped to increase the efficiency and inter-nationalisation of the today's oil production. Field developments are largely being based on subsea installations. Such developments result in increased requirements vis-à-vis competence, technological development and internationalisation for the supplier industry, as well as challenges with respect to players (employers, employees and the authorities) sharing the same understanding.

The potential within IO is estimated at NOK 250,000 million. The greatest value lies in the potential increase in the current value of petroleum reserves, i.e. financial dividends for operators and the Norwegian state (OLF 2006). The most important factors will be in-creased extraction from reserves in addition to production optimisation. However, realis-ing this increase in value requires the proac-

tive implementation of IO technology.Despite interesting estimates, there are

still many challenges: the supplier industry will be the primary player in this scenario in which innovation within technology and services will be absolutely essential. A large proportion of the innovation activities are taking place in small and medium sized companies. These often do not participate in industry forums and branch organisations very much since these meeting places are of-ten designed for the major players. The SME companies therefore have fewer opportuni-ties to promote their technology and raise capital. There is also significant potential inherent in getting competing companies within the offshore sector to work together and take advantage of each others' compe-tence in order to gain a stronger position in the international competition. Furthermore, there is little cooperation with other sectors on related technology (e.g. the Norwegian Defence Forces).

Small and medium sized companies of-ten have limited access to the financial re-sources necessary to develop ideas through to commercialisation and use. Furthermore, their rights are often poorly protected in the commercialisation of technology that is developed in project partnerships (IPR and incentives). Innovation Norway is therefore active in the market, promoting its industrial research and development contracts service, which takes account of this precise issue and in which the public sector puts up risk capital for technological development in partner-ship contracts.Innovation Norway has therefore estab-lished the Arena Integrated Operations, which is managed from our Rogaland of-fice (Stavanger) in cooperation with the

Hordaland office (Bergen). Its establish-ment was aimed at realising suppliers' po-tential, which represents both primary and secondary value creation, triggering sales of new products and concepts developed by the technology companies in the net-work, and contributing to accelerated un-derstanding and coordination of the SME supplier industry's positioning and the op-erators' and authorities' initiatives vis-à-

vis integrated operations.The ripple effects of this are also ex-

pected to have positive business economic and socioeconomic effects. In particular it will mean that small and medium sized companies will have an opportunity to present their technology and innovations in a larger context, which will strengthen their positions, and thus also the region and country as a whole.

iNGviL SMiNES

sector manager, oil & Gas, innovation norge

PHOTO: sTaTOiLHydrOintegrated operations allow tasks to be completed off-site, thus reducing costs related to the transpor-tation of personnel.


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