2nd edition – July 2012 / Published by Brodd Communication
Optimizing recovery One of Norway’s most powerful women, NPD Director Bente Nyland is in a position many would envy her. page 24 08 STATE OF THE ART NATION / 18 ENVIRONMENTAL MONITORING / 38 INcREASEd- ANd ENHANcEd OIL REcOVERy
INDUSTRY
DEEPWATER OPERATIONS
Photo: Statoil
Photo: Harald Pettersen - Statoil
Photo: Ă˜yvind Hagen - Statoil
Photo: Geir Otto Johansen - Statoil
www.og21.no
OG21 – Oil and Gas in the 21st century The OG21 strategy aligns the Norwegian petroleum industry around a common direction and ambition regarding technology challenges and opportunities. The main goal is to ensure a coordinated national effort on research, development, demonstration and commercialization. OG21 was established by the Ministry of Petroleum and Energy in 2001.
OG21 is divided into four Technology Target Areas (TTA’s) with their respective sub-strategies and visions: TTA 1: Energy efficient & environmentally sustainable technologies VISION: “Become the most energy efficient oil and gas industry in the world”
TTA2: Exploration and increased recovery VISION: “Make the Norwegian Continental Shelf a leading technology driven province by 2020”
TTA3: Cost-effective Drilling & Intervention VISION: “Enable economic advancement for Norway the next 100 years through 1st class technology development and application”
TTA4: Future Technologies for production, Processing and Transportation VISION: Technology for safe and environmental friendly production from any field The strategies can be downloaded at www.og21.no
Operators are moving into deeper water environments and expanding oil and gas production into remote regions such as the arctic. Siemens is a driving force in making these field developments technologically and economically possible. With power supply from topside or onshore, in-field subsea power distribution, control, surveillance and processing technologies, we are enabling field developments in the most challenging locations while improving recovery rates.
4 / brodd communication - july 2012
Combining this with advancements in engineering and quality for improved realiability and advanced monitoring, Siemens also offers best-in-class OPEX minimization. As an example, our industry leading subsea power systems integrate medium voltage switchgear, step-down transformer and variable-speed drives, enabling wider adoption of large-scale processing equipment in the subsea domain.
E50001-E440-F183-X-4A00
Siemens Subsea Solutions Enabling enhanced recovery and reduced lifting costs Solutions for the oil and gas industry
www.siemens.com/oilgas brodd communication / 5
introduction / trond olsen we recommend
Subsea growth:
How to make it happen? Just a few years ago, the subsea industry was in decline. Now it is back to full speed, maybe even in overdrive. Subsea markets will be blooming.
R
ecent data from analyst Rystad Energy predict operators spending in the global subsea market to grow from US$bn 32 in 2010 to 75 in 2015. For the period 2012-2015 they expect to see 1600 new trees onstream, on top on the installed base of 4500 by the end of 2011.
Opportunities also pose challenges Expected market growth demands access to more qualified personnel. My concern is that the forthcoming growth starts from a high level, and qualified recourses are scarce. In the years to come I expect to see the demand for equipment and services way beyond the capacity of the supplier industry. This will cause challenges both for the operators and the suppliers. There are two ways forward, both necessary in order to be successful in providing industry needs and secure energy supply in accordance with the growing demand. Access to funding for innovation and R&D is of vital importance when recourses are scarce. Lack of funding opportunities will most likely result in companies spending all their available recourses on delivering prodprod uct and services as demanded by the marmar ket. A triple helix model should be encourencour aged, utilizing a tight cooperation between government, R&D and industry. Incentives for innovation and R&D in specified areas, e.g. IOR and technology increasing HSE perper
6 / brodd communication - july 2012
formance and reducing manpower needs, should be prioritized.
Bringing new talent into the industry Can we bring unskilled and untrained personnel into our industry in order to increase the volume of products and services delivered and still have the high quality standards and HSE performances expected and demanded? The challenge is not solved by industry alone. Governments, universities and training/education institutions around the world must prioritize to establish additional and more relevant education and training programs for students. Companies must have structured and professional internal training programs to bring new employees up to quality and HSE standard. An extra effort should be applied to avoid «hijacking» employers from each other, and rather focus on bringing new talent into the industry. To recruit from your competitor, supplier or even customer is like putting out a fire with gasoline, it only makes the problem worse. The worst case scenario is that the cost of doing business becomes so high that it is not competitive. We can avoid it if we cooperate – government, R&D, education and companies.
TRONd OLSEN GENERAL MANAGER, NORWEGIAN CENTRE OF EXPERTISE SUBSEA
14
InsIghT Robots and drilling
20
InsIghT Reservoir surveillance
42
nEWs Making brave decisions
– Should an accident occur, evacuation begins. Robots don’t care if there’s a fire, in fact, they can be deck hands that fetch water to put out the fire. They can be sacrificed, says Kenneth Søndervik at RDS.
– You assume a certain productivity and the performance of each layer when you manage a reservoir. You need to be able to determine how each layer is doing individually and this has inspired the development of new surveillance technologies, says Brock Williams at RESMAN USA.
– When it comes to risk management, the important thing is that employees and leaders have deep operative knowledge, so-called hands on experience, says Norwegian Veritas’ Chief Operating Officer Knut Ørbeck-Nilssen.
Published by Brodd Communicaton Karl Johans gate 2, 0154 Oslo, Norway Phone: +47 21 04 21 00 Mail: feedback@broddcom.no www.broddcom.no Project manager: Kent Gasmann Phone: +47 938 13 879 Mail: kg@broddcom.no Design: Brodd Communication AS Coverphoto: Stig Jarnes Text: Pia Pedersen, Synne Hedlo, Gunn Iren Kleppe, Inger Lise Welhaven Distribution: Upstream/ONS/Maritime & Energy Print: Mortons Print Limited Feedback? Brodd Communication aims to produce magazines that inspire and provide insight to our readers. In order to achieve this we need all the feedback we can get. Please share your thoughts and ideas with us at: feedback@broddcom.no Disclaimer: This product and its content is the ownership of Brodd Communication. Usage of the content without written confirmation from Brodd ComCom munication is prohibited. Brodd Communication assumes no responsibility for errors in the content or alterations of the content.
dEEPWATER OPERATIONS, IN ASSOcIATION WITH OG21
Maximized recovery means maximized return on investment. And FMC’s subsea separation technologies, combined with water injection and boosting, represent a whole new way to maximize the reserves you can economically recover across a wide range of challenging conditions. So stop leaving all that oil in the ground. Discover the results only subsea processing can deliver. Learn more at www.MaximizeRecovery.com
TWO AWARDS for subsea separation:
MARLIM & PAZFLOR
inspiration / state of the art nation
WELL ANCHORED. – The OG21 strategy is well anchored in the petroleum industry since it is established by technology gap analyses carried out by the industry parties themselves, says Andreas Sandvik, director of OG21. PHOTO: Stig Jarnes
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/ inspiration
Success through collaboration
Norway is an industry leader in developing subsea technology for the offshore industry through the cooperation of a wide range of institutions. The joint effort has attracted international attention. PIA PEDERSEN, redaksjonen@broddcom.no
I
n 2001, falling oil prices and the lack of new oil discoveries on the Norwegian continental shelf, spurred the creation of OG21- Oil and Gas for the 21st Century. Initiated by the Minister of Petroleum and Energy, OG21 is a research and development task force consisting of universities, research institutions and operators and suppliers from the petroleum industry. OG21’s main objective is to assist the petroleum industry in formulating a national technology strategy for added value in the oil and gas industry, as well as increasing the export of technology. Andreas Sandvik, director of OG21, says part of their mission is to advise the Ministry of Petroleum and Energy on the prioritisation of public R&D funding. – We make recommendations to the MPE as to how the public R&D funding should be prioritised and used through the Petromaks and Demo2000 programmes, which are managed by the Research Council of Norway. The OG21 strategy is well anchored in the petroleum industry since it is established by technology gap analyses carried out by the industry parties themselves. Petromaks covers most of the petroleum-oriented research including both long-term basic research and applied research,
while Demo2000 is a programme for demonstration of new technologies, says Sandvik.
Five main areas of the future According to Sandvik, the industry is facing various challenges in the foreseeable future. He mentions five key areas that need special attention in research and development. – To ensure the continuing development of the Norwegian continental shelf, we are now focusing on the areas of subsea power transmission and distribution, integrity management technology, extended multi face transport, high performance subsea separation and real time condition monitoring technology. As we move further and further offshore, we have to develop new technologies to be able to operate in remote areas, for instance the North East Barents Sea. We also have to ensure environmentally sustainable operations, says Sandvik Senior Vice President of subsea and marine technology in Statoil, Bjørn Kåre Viken, elaborates. – Production on the Norwegian continental shelf started out in shallow waters and from there, expanded further north and further out. In areas with very deep water, the use of floating production facilities became favourable. From the time the first subsea production facility was started back in 1986, the improvement brodd communication / 9
inspiration / state of the art nation
FACTS
a state of the art nation Norway has become a state of the art nation in subsea technology. The essence behind this achievement involves three main factors:
»»A visionary government that applauds
innovation and technological development.
»»Enterprising oil companies that have shown a
willingness to invest and try out new technology.
»»Collaboration among a wide range of
institutions and a free flow of information.
and development of this technology has significantly improved. Thanks to the operators’ willingness to take risks and their courage to employ new technology, we’ve seen rapid developments in this area, says Viken. Over the years the offshore industry has got a lot of attention, engaging a wide range of skilled and talented people. The manner in which the Norwegian government has organised activity on the Norwegian continental shelf from the early stages has proved worthwhile. – They wanted research environments involved from a very early stage. They facilitated this and made it happen through applauding innovative solutions and technological development, says Viken.
Collaboration leading to a common strategy One of the reasons OG21 has attracted a lot of international attention is that the effort has led to joint strategising. Institutions collaborate on various issues, deciding on the direction to take and this is very beneficial for companies within the sector, according to Sandvik. – The Norwegian oil industry has quite naturally taken the front seat because of the challenges we have faced in the North Sea. We have to construct robust and innovative installations and have therefore invested in a lot of new technology. This has been made possible thanks to the willingness to take risks from companies
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like Statoil and Hydro Oil & Gas. The close cooperation between the operators and the technology sector with active support from the government has been essential, Sandvik adds.
A fast-growing industry During the past few decades, the North Sea and the Norwegian Sea have been experimental laboratories for the use of big gravity based platforms on shallow water, as well as in deeper water with floating structures and the use of subsea installations. The Norwegian export of offshore technology is growing rapidly and has passed NOK 120 billion per annum, says Sandvik. An increasing amount of oil fields discovered on the globe will be located deeper and
deeper offshore and in more and more remote areas. Subsea technology will become increasingly important and Norway is in a good position to take advantage of this, says Bjørn Kåre Viken. – Statoil is ranked as leader in subsea technology because of our advanced competence in the field. Over the years we have crossed some technology barriers and driven technology development in collaboration with suppliers. We see cutting edge work every day. We also find it exciting that companies we have worked with now are going global, says Viken.
Business opportunities Although the focus on research and sophisticated equipment is an important and inter-
COSTS Will increase. – As we explore more remote areas with more sophisticated equipment, the costs of intervention and maintenance will increase, says Bjørn Kåre Viken, Senior Vice President of subsea and marine technology in Statoil.
/ inspiration
Q&A
PHOTO: Stig Jarnes
with ANDREAS SANDVIK, director at OG21
»»What is OG21?
– OG21 stands for Oil and Gas in the 21st century. It’s essentially a task force that consists of operators and suppliers from the oil industry, research institutes, and universities. OG21 was established by the Ministry of Petroleum and Energy (MPE) in 2001.
»»How is OG21 organized,
and what is your objective? – OG21 consists of a board established by the MPE and a secretariat reporting to the board. The board reports to the Ministry of Petroleum and Energy and advises how the MPE’s R&D funding should be used and prioritised through the Petromaks and Demo2000 programmes. We also act in an advising capacity for the government and the industry.
»»What is your strategy?
– Our strategy is to encourage that all parties involved share information and work towards a common goal on national technological challenges and possibilities in the petroleum industry.
esting aspect, Viken points out that it is necessary to remind ourselves of the fact that it’s all part of a strategy to develop business opportunities. As we explore more remote areas with more sophisticated equipment, the costs of intervention and maintenance will increase. It’s crucial that we are able to develop new technology with a high level of robustness in a cost effective manner. – So far, we’ve seen that most of the installed equipment has delivered as promised. Our ambition is ‘Longer, Deeper, Colder’. Our strategy is to continue developing the technology needed to innovate the subsea factory – a subsea processing facility on the seabed. I’m convinced that we will achieve this, Viken concludes.
– We look at real challenges and collaborate and cooperate to find a consensus based solution. We outline strategies for governmental practice and for commercial businesses. By following our strategy, you ensure you are in line with the national industry needs. The strategy has led to a coordinated national effort within research, development, demonstration and commercialisation.
From the time the first subsea production facility was started back in 1986, the improvement and development of this technology has significantly improved.
The strategy is divided into four sub-strategies, so-called Technology Target Areas (TTAs):
»»TTA1: Energy efficient and
environmentally sustainable technologies. TTA2: Exploration and increased oil recovery (IOR). TTA3: Cost-effective drilling and intervention. TTA4: Future technologies for production, processing and transportation.
»» »» »»
Bjørn Kåre Viken, Statoil
brodd communication / 11
news / experienced exploration
HIgH HIT RATES DEmAND bOTH ExPERIENcE AND NEW TEcHNOlOgy
ON THE cuTTING EdGE. – To be leaders within our field, we have to constantly be on the cutting edge of technology, says Lundin norway’s exploration Vice President Hans Christen rønnevik.
To obtain high oil discovery hit rates, companies need skilled and experienced exploration officers. One of them is a geologist and the man behind the so-called elephant discovery in the north sea last year, hans Christen Rønnevik.
I
SYNNE HEDLO, redaksjonen@broddcom.no
n his work Rønnevik combines 15-20 year old seismic data with new information. – We do tests and gather new data, and then make use of the best analysis and processing technology. We’re a team, consisting of a number of specialists who all complement each other. We consider ourselves a learning community with a steadily increasing knowledge base.
Always searching for new technology – To be leaders within our field, we have to constantly be on the cutting edge of technology, says exploration Vice President Rønnevik. Rønnevik explains that the company he
12 / brodd communication - july 2012
works for, Lundin Norway, is an avid beta user of the latest technology. The company also helps with financing, while experimenting with a wide array of the newest equipment.
Seismic experiments
FACTs
commercial discoveries
»»The largest oil and gas reserves were
discovered during the 1970’s and 80’s.
A good example of Lundin Norways technosavviness is their testing of broadband seismic products. – We were the first ones to use them in 2009, and are currently using broadband seismic-technology from across an area of 2800 square kilometers. Again, this is a first, which came about after doing a test survey in the Sver Sverdrup region last fall, Rønnevik explains.
»»These discoveries have commanded large
High hit rate
»»The results the past 10 years have
– We have around 40 percent commercial success. This is very good in an international context. The company is behind 10 findings on the Norwegian continental shelf and uses NOK 2 billion a year on exploration. The secret is a balanced portfolio along with a high risk development strategy.
investments, research, development and comprehensive use of new technology.
»»Before 1995, 75% of all reservoirs were turned into commercial drilling sites.
»»The success rate for discoveries on the Norwegian continental shelf has increased in the last 40 years.
yielded findings in 50% of every well explored. However, the number of findings has decreased by 33%.
»»Experts suggest that future findings in available areas will be minimal.
Addressing key industry challenges
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insight / drilling
RObOTS ARE EFFIcIENT
Supporters of robotic drilling methods claim robots save time and money - also during the project planning phase. – You never know what is in the ground, but with robots you know how long the operation will take, says Kenneth Søndervik of Robotic Drilling Systems (RDS).
s
SYNNE HEDLO, redaksjonen@broddcom.no
øndervik is Vice President of sales and marketing in RDS - formerly Seabed Rig. The company uses solely robotic machinery in the actual drilling process. Time is of the essence during planning. – You can simulate each and every action, thus gaining immediate and accurate information regarding how long the operation itself will take. One concrete example is the logistics of using an elevator set up to move pipe of varying width. Usually this involves manual labor and resulting pauses to change pipe width. While this now takes approximately 15 minutes each time width is changed, on a robotic drill deck this process would be ongoing and automatic. Another example is during the retraction of drill pipe. Today this is dependent on the expertise and constant focus of the personell. Meters of pipe retracted over time varies during shifts and between teams. With a robotic drill deck you will know the exact rate per meter in advance, also guaranteeing that restrictions and regulations posed by operations and service companies are followed to the letter.
Health, safety and environment improved Much of the work in the North Sea can be both repetetive and heavy - thus increasing risk. When machines do these jobs, what used to be potentially dangerous can be done again and again without risk of personal injury. – It makes crush and fall injuries redun-
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If something accidentally strikes a robot, the consequences are relatively minimal. Kenneth Søndervik, Vice President of sales and marketing in rDS
dant. If something accidentally strikes a robot, the consequences are relatively minimal. Getting hit in the head with a wrench can be potentially fatal. Robots can be life saving in the case of major accidents. Not only don’t they need to be evacuated,but they can keep working as long as this is possible. – Should an accident occur, evacuation begins. Robots don’t care if there’s a fire, in fact, they can be deck hands that fetch water to put out the fire.They can be sacrificed,says Søndervik.
changing infrastructure On a robot run rig, the infrastructure is different. Machines can stand closer together, there is less need for offices, rooms, hallways etc. Søndervik says rigs will become smaller. – Robots and the way they move can be designed in a much more compact manner. When we shrink these elements, the size of the rigs themselves will shrink. He is, however, aware that machines don’t last forever. They need service, and there are areas that require specialization. Human workers will, in other words, still be in demand.
What are the benefits of using robots in the drilling process? Kenneth Mikalsen, CTO in Robotic Drilling Systems sums up which advantages one can expect. 01 INcREASEd EFFEcTIVITy Robots receive instructions for specific job duties, who they will interact with and who they should look out for. One of the largest areas of savings is how the machines interact with one another. The machines in the well communicate with those over the well, who then interact with geologists.
02 IMPROVEd HEALTH, SAFETy ANd WORK ENVIRONMENT An oil rig is a hazardous workplace and platform worker’s jobs involve some risk.
/ insight ROBOTIc SySTEM AT THE SEABEd. Unmanned seabed drilling rig installed at the seabed in arctic waters. Drilling is performed by a robotic system at the seabed, while the rig is connected to a mud, control and power umbilical from a surface vessel. Because the drilling operation is conducted on the seabed, the surface vessel has flexibility in its position.
Q&A cMR – GREEN dRILLING TEcHNOLOGy OF TOMORROW
PHOTO: rDS
Odd B. Skjærseth, WDP CeO
»»What makes continuous Motion Rig
(cMR) technology so «green»? – it reduces CO2 and nOX emissions by over half. The reason for this is that the time needed to drill a well is cut in half. Power consumption is also 25-35percent lower because the the rig moves continuously without stopping. There’s no acceleration and breaking involved.
»»How does cMR reduces the risk of
oil and gas related catastrophes? – Since CMr moves continuously, there isn’t any pumping going on in the well, avoiding gas suction from the reservoir. This also prevents gasses from seeping to the top which can potentially lead to an explosion with consequences for human health and lives as well as environmental damage.
»»How can you say ‘cMR makes drilling Minimizing accidents saves lives. Much of the risk involved comes from working at night, irregular work/sleep schedules and lack of sunlight. repetitive duties can lead to concentration problems and stress injuries. robots can take over these high risk jobs.
03 WORKFLOW not all teams deliver equally when it comes to quality and performance but robots provide consistent results. They are also able to troubleshoot some of the potential human errors that can cause project delays. A need to evacuate in the event of an accident is prevented. robots work until the job is done.
04 cONTROLLING cOSTS it becomes possible to calculate the cost of
projects by measuring the amount of time a robot will use to complete a task. robots also provide information on which parts need shifting. An example of this would be discovering that pipe number 467 has worn threads and needs to be replaced.
05 FOcuSING ON THE PROcESS employees can then turn their focus on what is happening in the wells with a sense of certainty that the job is being completed correctly. issuing commands means not having to think about how to do the job, it just gets done.
06 INcREASEd PREcISION The use of robots on the drill floor increases the precision and predictability of the drilling program.
geothermic wells sustainable’? – Today geothermic energy isn’t sustainable because drilling for energy is too expensive. By cutting drilling costs in half, you correct those margins.
»»you also claim that ‘cMR technology
will lead to increased expertise as well as business opportunities for green energy in Norway. How so? – if the norwegian offshore industry would facilitate a transfer of technology and innovation, so that we can deliver competitive products and services, that in itself will lead to an increase in expertise as well as new possibilites for businesses in the green energy market.
brodd communication / 15
insight case / drilling
The world’s first
VIRTUAl drilling plant delivered
Recently, West Drilling Products (WDP) created the world’s first virtual, fully robotic drilling plant. The plant uses Continuous Motion Rig technology, enabling drilling in all types of wells continuously.
B
y utilizing Continuous Motion Rig (CMR) technology, it’s now possible to continuously drill, continuously circulate and to connect drilling pipes without halting operations. The technology also enables the development of a fully robotic drilling rig which drills in all types of oil wells without the need for stopping during the process. The technology enables the development of a fully robotic drilling rig, which also has the potential to not only cut drilling costs in half, but also Co2 and NOX by half as well. Odd B. Skjærseth, Mads Grinrød and Bjørn Eilertsen are the men behind the innovation WDP is now developing. Skjærseth is the company’s CEO.
WdP virtually tested the technology Through industry collaboration costing NOK 20 million between Statoil, ABB, WDP and Innovasjon Norge, WDP was able to build the CMR technology virtually on a scale of 1:1. The virtual rig will be used in the designing and testing of future models.
The virtual machine becomes a reality WDP is now building the CMR Pilot project, in cooperation with Statoil, Shell, Conoco Phillips and ABB The oil companies will also contribute with financial support as well as operational and rig management expertise. The project is partly funded by the Norwegian Research Council through the DEMO 2000 program,
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cONTINOuS MOTION RIG (cMR). The new and faster Super Double CMr Land rig from West Group. PHOTO: WeSTGrOUP
achieving the highest funding for any one single project funded under this program ever. ABB, a world leader in robotics, will deliver the robotic control and automation. Thus the CMR pilot will be the world’s first fully robotic drilling plant and will be placed at Ullandhaug in the Stavanger region beside today’s Ullrigg.
In cooperation with others Those responsible for the development of the pilot are cooperating with several others to see the project through construction, fabrication and to get the Rig operating. The collaboration with Ullrigg and IRIS is essential for the projects success. The research environment at Ullandhaug is a world leader in drilling and wells. – For our company, it’s important to utilize the oil clusters in the region, says Odd B. Sjærseth. The rig will be fully robotic and there will be no personell on deck. There will be no risk of personal injury.
FACTs
norway’s oil capital
»»The city of Stavanger, situated along the North Sea, is Norway’s oil capital.
»»Statoil, Norway’s largest oil company,
has their headquarters here. Several international oil companies also have their Norwegian headquarters in Stavanger.
»»Petoro, who safeguards the business
relations with the government’s involvement in the petroleum sector on the Norwegian continental shelf, is located here.
»»Offshore Northern Seas (ONS) is one of
the largest exhibitions of it’s kind in oil and gas. More than 1350 exhibitors and close to 50.000 visitors from all over the world find their way to the exhibition.
k has Devote e nd r e h -W ation a A tu F c L a s n u io Lex nsmiss ergies ped tra ted syn a e r c develo s ns. , ha sollutio system a e l s o b tr u n s co dvance also a which
Badger Explorers semiautonomous drilling probe
A few other projects where Devotek has contributed actively are
Control system for deflectors used in the seismic industry
Safety actuator for BMW, Audi and Mercedes - and where the same concept is being used in other industry sectors as well
Which synergies may be found between technologically demanding solutions for automotive versus subsea oil & gas systems? Dr. BÅRD VESTGÅRD Manager Technology
C
omparing the two actually reveals a number of similarities. Compared to drilling, for example, the driller and driver are synonymous in that they both master rotating mechatronic machinery operating in varying terrains, while relying on experience as well as support from more or less automated subsystems. Furthermore, both rely strongly on efficient, robust and safe systems since consequences may be severe in case of poor performance or accidents. With our background from automotive development and experience from other industries the last ten years, we have learned that exchange of methods and solutions across domains is very valuable. A bold statement perhaps, but we believe that subsea could benefit from the systematic approach to product development that automotive has been forced to learn under extremely competitive conditions. Future subsea drilling and production architectures will be more interconnected and require a higher degree of autonomy. They involve ever more sensors, actuators, software and processing power. This will be true for both existing and remote future wells. For example, In-Vehicle communication networks in cars, such as CAN and LIN, secure minimum copper wiring and full availability to important data – across supplier platforms and according to agreed industry protocols. Every critical component or system module is continuously monitored and analyzed by an on-board diagnostic system (OBD), and their status reported to the master electronic control unit (ECU).
During development or after a road problem a record (read black box) is available for asserting and learning. Subsea is currently moving toward this level of detail integration, realizing that getting there is a question of more than just standardization. When the well and production system is properly instrumented and actuators of sufficient reliability and bandwidth are in place, extended autonomy through integrated automation is possible. A Lean Systems Engineering approach to planning and realizing new automation, such as within managed pressure drilling (MPD) or subsea well boosting, is desirable. Such a process should start with careful definition and analysis of customer needs, followed by clearly understood specifications where requirements are traceable and linked directly to FMEA’s, system architectures, and validation programs. Ownership to the requirements must be defined and compliance enforced throughout. This assumes tight cooperation between the field operator and suppliers and supports successful development all the way to the optimal system architecture. This may sound tedious but experience shows that such a coherent approach leads to the right product performance, cost and timing. It is in such a context we believe Devotek can contribute with valuable competence: Cooperation with several different branches gives us a unique opportunity to bridge technologies/ 17 brodd communication between branches.
www.devotek.com
news / environmental monitoring
Predicts demands for environmental monitoring The leader of environmental monitoring in OG21, Helge Skjæveland, believes authorities may very well demand that all wells in Norwegian waters be monitored. SYNNE HEDLO, redaksjonen@broddcom.no
T
he group Helge Skjæveland leads at Technology Target Areas (TTA1), has set out to establish a national strategy for energy effectiveness and environmentally friendly/ sustainable technology in the oil sector. The oil and energy ministry has previously initiated OG21, as a coordinated effort within the petroleum sector to combine education, research, innovation and commercialization.
The cold creates problems Northern areas of the Norwegian continental shelf are especially environmentally sensitive. Thus oil exploration in the Barents Sea has not yet been launched. – Due to the delicate environment, the distance from existing infrastructure, its freezing climate and the ice in this area, cleaning up potential oil leaks would be very difficult. The risk of accidents must be reduced further before operations there can be allowed. But if this does happen, real time monitoring will be essential, says Skjæveland. The main problem is that hydrocarbons take longer to break down in cold climates. – Had the Deepwater Horizon accident happened in Svalbard, the oil wouldn’t have been broken down so quickly, according to the TTA1-leader. Many of the oil fields in the North Sea are already monitored and controlled from land. This development will continue, and in the future the inclusion of systems and sensors on both the ocean floor and along oil pipes that discover potential leaks immediately, will most likely become standard.
Launching in 2015 In 2011, Statoil joined forces with Kongsberg Oil & Gas Technologies on a project costing NOK 150 million. As partners, they are in the process of developing the world´s first Environmental Management System for the oil and gas industry.
18 / brodd communication - july 2012
Had the Deepwater Horizon accident happened in Svalbard, the oil wouldn’t have been broken down so quickly. Helge Skjæveland, OG21
– We have partially tested this technology on the subsea level of the Norwegian continental shelf. An integrated environmental management solution will be ready for launch in 2015, says Mona Låte, head of R&D in Environmental Management in Statoil. Låte believes there are huge advantages for documenting environmental data in real time and integrating the information in day to day operations. – The biggest advantage is that we can discover small leakages earlier and prevent larger accidents.
Measuring changes in the environment Låte says the company thinks in terms of life cycle processes when it comes to surveying the environment. An analysis comprises facets of mapping, the exploration phase, the drilling phase and further operations. Statoil monitors Norwegian waters with cameras and thermometers and observes changes in light, salt, electricity, turbidity and chemical parameters. Off the coast of Brazil, the company monitors algae calcium deposits to keep track of environmental changes. – The deposits change colors when they experience stress and are an early warning if something is wrong.
FACTS
norwegian petroleum safety authority
»»One of the main priorities of the Norwegian Petrole-
um Safety Authority for 2012 is that the industry has as a goal to prevent accidents that can lead to acute emissions. Considering the accidents with Deepwater Horizon in the Gulf of Mexico and on the Montara oil field in Australia, it is clear that prevention of large accidents starts with the surrounding environment. This is why the Authority authority encourages all forms of preventative measures.
Innovative research and future value creation Increased oil recovery has been one of IRIS’ (International Research Institute of Stavanger) key research areas for years. The institute has an innovative profile and our role is to support the industry’s value creation, taking safety and environmental impacts into account.” Aina M. Berg, Director of IRIS Energy
Increased oil recovery Increased oil recovery at IRIS covers both reservoir technology, drilling- and well technology - two areas where technology- and environmental research are linked together. The goal of our research is to contribute to increased oil recovery and at the same time keeping safety, environment and cost efficiency as a top priority. To improve the financial feasibility and minimize the environmental impacts, are two sides of the same coin, Berg explains. The research institute was a key actor in transforming the drilling industry from a manual to a mechanical workplace. It’s now playing a similar role as the industry moves towards automated drilling. An automated approach enables fast and reliable early detection systems that prevent blowouts or other industry problems that cause costly disruptions in production. New downhole sensors provide more data to be processed and analyzed in real time and is highly suitable for decision making, says Berg. We believe automated drilling is the future. IRIS has developed two different software tools supporting the drilling process that are available on the market todayDrillTronics and DrillScene. One of IRIS’ daughter companies, Sekal, owns and provides services using these tools. Statoil recently signed a framework agreement with Sekal to use DrillScene for Statoil’s drilling activity.
Testing, training and development Outside IRIS’ headquarter there is a full scale drilling rig (ULLRIGG) suitable for testing a vast variation of technologies - both hardware to software. Testing in a real and safe environment helps shorten the time between research and development and its implementation offshore. Currently ULLRIGG is beeing upgraded and modernized making it fit to serve the industry for years to come. Environmental safety Environmental safety is a priority amongst all businesses in the offshore industry and IRIS has ongoing studies regarding the effects of the petroleum sector on living organisms, both in the water column and on the sea floor. IRIS, along with support from the industry, is developing innovative environmental surveillance methods and biological models to predict the effects of drilling.
-How deep sea coral will adapt to a changing world is still unclear but the combination of industry and increased CO2 in the ocean does put a strain on these ecosystems, says Durand. New strategical developments lead to a strengthening of IRIS’ core research areas within oil exploitation. Together with the Norwegian Research Council, the petroleum industry and the European Commission the division is heavily involved in long-term theoretical and operative projects, some of which have openings for new affiliates and sponsors.
-We integrate field observations with experiments involving fish, shellfish and coral while using biological models to gain further insight into the environmental effects. We supply a basis to create sustainable development in offshore activities, says Dominique Durand, Director of IRIS Environment. Coral reefs are important to the entire ecosystem at deep sea levels off the Norwegian coast. IRIS’ researchers are interested in getting solid indications of what state of health the coral reefs are in.
ULLRIGG is a full scale drilling rig used for testing , training and development.
brodd communication / 19 firmapost@iris.no | www.iris.no
insight / reservoir surveillance
RESERVOIR SURVEIllANcE TEcHNOlOgy
Optimal reservoir management involves predicting the flow rate and depletion rate of each layer within a multi-layered reservoir interval. PIA PEDERSEN, redaksjonen@broddcom.no
W
ithout across the reservoir surveillance, these predictions are based on a lot of assumptions. The need for this information has inspired innovative technology development in reservoir surveillance information. – With the current state of technology it’s fairly easy to measure downhole pressure. It’s commonplace to deploy a pressure gauge right above the reservoir interval but in deep waters the reservoirs consist of a big package with a series of reservoirs. A downhole pressure gauge deployed at the reservoir interval will provide information about the rate of depletion from the whole reservoir but not how each individual layer is per-
FACTs
ways to survey all the layers in a reservoir There are four ways to survey all the layers in a reservoir:
»»Fibre optical equipment, deployed into the
completion equipment deployed across the reservoir.
»»Electronic based temperature sensors, also deployed across the reservoir.
»»PLT, intervention faced, deployed at the end of the cable while the well is flowing.
PHOTO: reSMAn
»»Wireless surveillance system using sensi-
tive tracers without any communication lines necessary.
20 / brodd communication - måned 2012
You assume a certain productivity and the performance of each layer when you manage a reservoir. Brock Williams, RESMAN USA
forming, says Brock Williams, General Manager at RESMAN USA. – You assume a certain productivity and the performance of each layer when you manage a reservoir. You need to be able to determine how each layer is doing individually and this has inspired the development of new surveillance technologies, says Williams.
Good, but not good enough One solution is integrating fibre optic cable into the completion equipment across the reservoir but, according to Williams, this has proved elusive for deepwater completions. – Fibre optics have been challenging to integrate in deepwater wells. Electronic based temperature sensors have also been developed for deployment across the reservoir interval. Both of these require continuity to transmit the signal from across the reservoir to the surface. This presents a lot of challenges. The production logging tool, also known as the PLT, is also an intervention based solution. – This is a very good tool for understanding how each individual layer is performing. It’s a very sophisticated electronic device that gives good information. However, it can cost several million dollars to perform one survey and it’s a risky operation, says Williams.
Information is the key
To enable operators to manage oil and gas reservoirs properly, enough reliable information is vital. With new, wireless surveillance technology, information gets through without the risk of damage to wires. The surveillance technology monitors the inflow of oil and water. This is important information, giving operators an important understanding of well performance from clean up to steady state production. They obtain the necessary data to manage their field strategy and update their well and reservoir models, says ed Leung, VP of Well Technology in reSMAn.
/ insight
Q&A RESERVOIR SuRVEILLANcE We asked Brock Williams at RESMAN USA to fill us in on the topic of reservoir surveillance.
»»Why is it important to have
surveillance of a well, and extract information from all the layers? – Because gross intervals can exceed 1000 ft thick, if you have a pressure gauge on top of the package, it’s impossible to determine each of these layers individually. In a typical deep water reservoir, the water displaces the oil. It drives the oil through the reservoir. With water pushing through the rock, the water will at some point, start to enter the well. If you only have a single pressure gauge located on top, it isn’t possible to determine which layer is the source of the water production. Knowing which layer is the source of water production allows more efficient management of the water flood.
»»How does surveillance help
the operators? – When you manage a reservoir you predict how each layer will perform. A lot of the predictions are assumptions formulated before drilling has begun. Surveillance will help assess how good of a job has been done.
– Without surveillance it isn’t possible to manage the field properly nor maximise recovery. With reliable surveillance information, it becomes possible to identify well integrity problems or the location of water breakthrough. This enables operators to make informed decisions to work over the well knowing precisely where the problem occurs, says Leung.
– There is no risk involved with an inflow tracing system. instead of using fancy, electronic devices that could easily fail, we have intelligent chemical tracers that release either to oil or water which can be sampled at topside to determine what fluid is flowing where and how much across the production intervals, says Leung.
New, wireless technology
– We now have over 100 installations working flawlessly around the world since the system was successfully piloted in 2007. As long as the well flows fluids to surface, RESMAN will always be able to provide surveillance information, says Leung.
Today’s technology involves communication lines from the surveillance technology to surface. Wires risk being damaged or broken during installation. The reSMAn technology eliminates this problem completely.
When a well is performing below expectations, surveillance information can help determine whether the cause is geology or completion efficiency. The root cause of the problem is then utilized to make changes in that and future wells.
»»How frequently do operators acquire
across the reservoir surveillance information from deepwater wells? – The majority of operators never acquire across the reservoir surveillance due to the current state of technology adds significant complexity and risk. This is spawning developments in wireless reservoir surveillance technology.
brodd communication / 21
panel of experts / a recipie for success
QUESTIONS FOR THE PANEL deepwater operations
Stig H. Christiansen CEO, Add Energy Group AS
GUNNAR BIRKELAND CEO, Polytec
Tormod Veiberg
Drilling Superintendent, AGR
How has the Norwegian offshore industry come so far?
A rich shelf and wise political decisions creating The Norwegian Model with a stable fiscal and regulatory framework developed to optimize our shelf’s resources in a safe and environmentally friendly manner. Plus later tax incentives for exploration, license rounds, and our harsh environment requiring technological edge.
The demanding customer was adapted by Statoil and later Gassco from the Norwegian Authorities. The people on the west coast of Norway has been used to adapt to changes over decades. A demanding customer served by suppliers willing to adapt, compete and find solutions is a powerful toolbox.
Since the oil industry began in Norway, the requirements set out by the government have challenged the industry, forcing it to continuously improve technically within the areas of organizational setup and safety. The know-how and working attitude has contributed to a world wide industry.
Which aspects should be prioritized in order to become even more cost efficient?
Fast track developments, subseaand tie back solutions and life extension combined with transport-infrastructure developments, sourcing of cost-efficient capacity and skill from abroad, transfer of practice and standardization. And of course continuous R&D.
Standardization of technology offshore and subsea will require more use of simulation tools and validated models which will lead to more cost effective technology and operations. Operators requiring fuel efficency for offshore vessels wich will lead to a stepchange in global maritime fuel consumption.
The number of dry wells needs to be reduced. Technology must be further developed and models to improve potential optimized. High activity level on the NCS dilutes the competence level. This should be given higher focus both with respect to safety and operation.
What should the industry do in order to defend their market leader position globally at NCS?
Continue the path developed since the late 1960’s: Be predictable, offer exploration incentives, active acreage management and possibly looking at the overall tax level as complexity (deep water, HTHP, remote etc) shifts more risks to operators who should get return on this “know-how” based risk-taking.
The companies with the best innovative nettwork making the fastest and best risk managed decissions will win. Specialist competence have to be closer to the demand and the customer have to be even more demanding. Safety, efficiency and technology development is a winning stragtegy.
Continuously search for improved solutions and new technologies; stay attractive to the major oil companies. The industry should be a pioneer for oil industries in other parts of the world
The New Procurement Wheel For buyers - a free and open online service: Effective distribution and management of enquiries Global Sourcing: update on potential suppliers, new products, services and technology For sellers - with M&E membership: Listings in The Procurement Wheel to receive more enquiries from more buyers worldwide. Launching of new products, services and technology Sign up for membership at www.maritimeandenergy.com Contact: post@maritimeandenergy.com 22 / brodd communication - july 2012 www.maritimeandenergy.com
• Do you know if all your zones are producing? • Do you know where water breakthrough is occurring? • Do you know how your production profile is evolving over time?
If not, we can help. Learn more about our intervention-less, risk free solutions. RESMAN will be presenting & attending at the following events: AUG. 28-31
ONS, Stavanger, Norway
SEPT. 10-13
SPE ATW “Pushing the Envelope in Sand Control, Barcelona, Spain
SEPT. 17-20
Rio Oil & Gas, Rio de Janeiro, Brazil
SEPT. 23-26
SPE ATW ‘’ Integrated Intelligent Completions’’, Bali, Indonesia
OCT. 8-10
SPE ATCE, San Antonio, Texas
OCT. 22-24
SPE Asia Pacific Oil & Gas, Perth, Australia brodd communication / 23
www.resman.no
portrait / bente nyland
A passion for oil Passionate about her work, NPD Director General and geologist Bente Nyland loves a challenge. After five years on the job, she is well-liked and respected. And with twenty-eight years in the field, she has seen her share of excitement. GUNN IREN KLEPPE, redaksjonen@broddcom.no
B
ente Nyland enjoys her job as Director General of the Norwegian Petroleum Directorate (NPD). No wonder. Ever since day one, oil and gas reserve estimates have been on the rise. After a lull, new discoveries have been made and increased recovery is now possible even in older fields. – The high price of oil has made decisions to keep exploring and to develop older finds easy. Even discoveries from the 70s have now been developed and made profitable, she says. – Each day is different; there are always new challenges to deal with. Every discovery and every field is also different, so every solution has to be tailor made, she explains about her job. Nyland, a geologist by profession, originally dreamt of going into biochemistry. At one point, however, she realized that “everybody else” was thinking along the same lines, and changed her mind.
A passion for geology Inspired by other geologists, she decided to give geology a try. After one semester, there was no going back. – If there is anything I regret, it’s not getting into geology sooner, she says about her career choice. Oil and gas, however, was not yet on her mind. That happened later. And at time of hire, there was a great need for geologists on the Norwegian
24 / brodd communication - july 2012
Continental Shelf (NCS), as there is today. – There is a lot yet that needs to get done, Nyland says about future hiring needs. An entire generation of professionals will be retiring in the next few years, which gives her some concern. Alternatives include importing professionals, accomplishing more with fewer people or just plain doing less. For perspective, 70 fields are kept in production today with the same number of people needed to keep 20-25 fields going twenty years ago. Nyland is disappointed, however, that science and technology are not among kids’ top educational choices. With a solid foundation in the sciences, they’d have more choices later. – It’s important not to close any doors, she stresses. She has great faith in teachers’ ability to inspire—which is what happened in her own case. To her, good science teachers are crucial for future recruitment.
Teaching important – I emphasize teaching everywhere I go, to the point that I get tired of repeating myself. Though, for many the topic is new. It is a complicated topic, but it’s important to assure the public that we are managing the resources wisely, that we are serious about safety and the environment, and that this is worth doing, she says. Nyland loves a challenge. In fact, problemsolving is the favorite part of her job. – We [NPD] operate at the crossroads between politics, administration and industry. Operating within that nexus provides perspective, she
explains. Decisions made here, often have significant consequences. Not too lousy when those consequences involve more money “in the bank” [Norway’s pension fund]. – You also come to have some understanding of political processes and ways of thinking, she continues. – Technology and nature cannot always be managed through lawmaking, so finding the best possible solution is always interesting.
Innovation Nyland especially enjoys watching solutions being developed at home, before being introduced on the global market. That includes subsea technology, which is now commonplace. – We have accomplished a lot, she says. One example is developing smaller fields such as Ormen Lange, which requires longdistance subsea pipelines. – That will only become more common, she predicts. Nyland has witnessed her share of innovations during her twenty-eight years in the profession. Production life-time has been extended for many existing fields. Just one per cent increase means a considerable increase in production. Besides, improvements in seismic modeling make new discoveries possible where they had been overlooked before. – This is one of the most important recent developments, she argues.
Sharing the knowledge Yet another favorite is NPD’s involvement in Oil for Development under NORAD. For one,
/ portrait
KEEP ALL DOORS OPEN. – It’s important not to close any doors, Nyland stresses. She has great faith in teachers’ ability to inspire—which is what happened in her own case. To her, good science teachers are crucial for future recruitment. PHOTO: sTIG JARNES
brodd communication / 25
portrait / bente nyland
she finds learning how other cultures deal with different challenges, very interesting. – You can’t just copy-paste Norwegian solutions to other nations and expect them to work, she points out. The fact that some developing countries are starting to see some success, is very encouraging to her—especially when it benefits a country’s entire population instead of a privileged few. Any free time at all? – Yes, she assures us. That often means reading for Nyland, who admits lagging behind. – Whenever I travel, the first thing I do is to find a bookstore, she continues. This summer, reading is first on the agenda. Travelling is also enjoyable, and cities with history are of special interest.
26 / brodd communication - july 2012
A different breed of tourist According to Nyland, geologists prefer “exotic” destinations. This, to them, means areas with interesting geological features. Offshore geologists especially enjoy seeing geological features on shore, which they cannot otherwise see under water. This includes Svalbard and Greenland, where the continental shelf can be viewed above sea level. Spain is another favorite—not for the reasons most people enjoy the destination, but because of its geological features. – If you ask a geologist for the most exciting destination worldwide, they’ll say the Bahamas. Its geology is just like that of the Barents Sea…. – Geologists have a terrible sense of time, she jokes. Short term means a million years,
long-term a hundred million. Nyland doesn’t worry about the near future, however. In fact, she is quite optimistic. – It all comes down to demand. What will future energy demands be like? There will certainly be a greater energy mix. The question is how much energy can wind, wave and solar produce? I do see a growing energy demand, and there is a growing population. Until we have efficient distribution of alternative energy, oil and gas are quite efficient.
Forty more for sure – Norway should be able to deliver for a long time, but we are past the peak. Production is bound to decline, but we will see a long, slow decline into the future, she predicts. – Our re-
/ portrait 40th anniversary. The NPD celebrated their 40th anniversary on June 14 th with a “birthday party” in the canteen for all the employees. PHOTO: MARIE VON KROGH
profile
TIPS
BENTE NYLAND Born: 1958 Education: MS, Geology, University of Oslo, 1984 Experience: Director General of NPD since 2007. Senior Geologist since 1984, leadership role since 1989. Previously at Statoil (5 years) In the news: Considered one of Norway’s most powerful women
BENTE NYLAND’S MANAGEMENT ADVICE What kind of leader would you want?
1
Grow—and hire—future leaders.Trust and responsibility foster growth. Show your people that you trust them and give them responsibility. If somebody disappoints occasionally, bring it up separately—and in private.
Make sure you take time off!
2
Leadership does not have to equal 24/7 work. Show others the job can get done during regular office hours— with minor exceptions, of course. Watch out for unnecessary extra work. After all, you have an organization whose task it is to execute the job. If you don’t limit yourself and take on too many responsibilities, you risk hitting the wall sooner or later.
Delegate tasks!
3
This means you have to accept a job done differently than you would have done it yourself. Be conscious of where you set your limits of acceptability. This is something you may have to learn as you go along. Be conscious of what tasks you delegate and which tasks you prefer to execute yourself.
Inspire people!
You can’t just copy-paste Norwegian solutions to other nations and expect them to work. Bente Nyland
sponsibility is to make sure production goals are met and to increase recovery whenever possible. Once you shut down a field, the game is over. The question is profitability versus costs. An important consideration is how long can you keep production going. This year, NPD is celebrating its 40th anniversary. – NPD will definitely be around for the next forty years, Nyland assures. – At the time when I took over as Director, the situation was quite dire. I suspected that I would be the one to close it down. Today, I am confident that this will still be an important industry after I retire. So, how will you spend your retirement? – I see myself in Provence, enjoying a glass of good wine, reading books I haven’t yet read, perhaps even painting a bit.We’ll see what happens.
4
A flat, hierarchical structure with cross-functional teams and few in top management works well for us, who have a lot of projects going on. A short distance between team members and top management inspires people and gives each person real influence.
Rotate leadership roles!
5
This is important for providing opportunities for advancement within the organization, as well as for providing dynamics and preventing rigidity. This organizational style fosters initiative but may not be ideal for the less independent individual.
brodd communication / 27
news / multiphase-compressors
Compressing gas on the ocean floor gives enormous savings Advancements in subsea technology make the compression of gas in close proximity to the reservoirs possible. The savings are in the billions of kroner. PIA PEDERSEN, redaksjonen@broddcom.no
g
as is compressed by adding energy to the well stream with a compressor. This adds pressure to the gas, resulting in lower transportation costs and energy demands. The driving principle behind subsea gas compression is to get more gas out of the reservoir. This is possible because of the naturally increased pressure at subsea levels, in turn making a higher degree of pressure at the receiving end possible. This also allows for postponing periods of lower capacity, but remains a constant challenge for installations on the Norwegian continental shelf and many other gas producing areas. Traditionally one has expanded the compressing facility on the platforms themselves. But at this point the gas has lost so much pressure that extra energy is needed in order to get the gas back to its original pressure levels for processing and transportation. It is therefor immensely cost effective to compress the gas as early in the process as possible, explains Nils Arne Sølvik, Sales Manager for Pump and Subsea Process systems, WH, Framo Engineering AS. – The trick is to use underwater compression in order to send as much gas as possible through the pipes and the processing facility. By compressing as close to the reservoirs as possible, in fact on the ocean floor, you increase energy at the point where there is least amount of decompression, says Sølvik.
The trick is to use underwater compression in order to send as much gas as possible through the pipes and the processing facility.
FACTs factoids
Expanding gas reduces the total capacity in the production system as a whole.
»»By compressing on the platforms, the gas loses a lot
of pressure and extra energy is required to return the gas to it’s original pressure level.
»»By compressing gas on the ocean floor, floor you are only
Extremely robust and advanced Compressing gas right at the reservoir does create challenges, because unprocessed gas contains water, condensation and particles. – We have designed an extremely robust compressor. It can handle everything from 100 % fluid to pure gas. We are the the only company that
28 / brodd communication - july 2012
makes multiphase-compressors. Other solutions exist, but they need a larger subsea processing facility to work. Ongoing tests that compare subsea to top side compression, conclude that enormous savings and increased profitability are attainable by choosing the subsea solution. – Modifying existing platforms is very expensive and isn’t as safe as a subsea solution. Ultimately we’re talking about making billions by going subsea, Sølvik explains. The sophisticated subsea compression equipment is now being set up for use at Åsgard, Ormen Lange and the Gullfaks platforms, amongst others. - Subsea facilities based on our technology don’t require liquid pumps, gas separators or advanced processing equipment, and are therefor smaller, more cost effective and reliable. This is the most advance equipment Norwegian subsea industry has commer commercialized, something we are very proud of, Sølvik adds.
expending energy where the least amount of decomdecom pression has occurred.
»»Through the use of subsea gas compression, Gullfaks C has seen an increase in exploits from 62% to 74%.
Nils Arne Sølvik, Multiphase compression expert
 � � � �
brodd communication / 29
news / konkraft’s recommendations
IOR:
cHAllENgES AND OPPORTUNITIES
Increased recovery represents a number of challenges – and opportunities – on nCs. Despite an already high recovery factor, enormous reserves are left behind and possibilities for value creation are missed.
cHALLENGES ANd OPORTuNITIES. – There are challenges and opportunities ahead in implementing the suggestions, says Hans Petter rebo, Konkraft Leader. PHOTO: KOnKrAFT
T
GUNN IREN KLEPPE, redaksjonen@broddcom.no
his spring, KonKraft presented their recommendations on IOR and cost reduction. KonKraft is a collaboration between the Norwegian Oil Industry Association, the Federation of Norwegian Industries, the Norwegian Ship Owners’ Association and the Norwegian Confederation of Trade Unions. The group had been assigned the task of drawing up recommendations based on a recent report on increasing recovery (the Åm committee). In order to accomplish this, task forces were established in the areas of contracts & procurement, reservoirs & wells plus cost reduction & strategy. Their recommendations include initiatives within technology, subsea, standardized contracts, continued improvement, cost reduc-
30 / brodd communication - july 2012
tion and life-time costs. – Those are some of the most important areas, KonKraft Leader Hans Petter Rebo points out. One example involves reviewing and updating existing standard contracts in order to reduce contract administration, enable more suppliers to bid on contracts, and reduce smaller companies’ need for such expertise. – It is about contract efficiency and cost reduction, Rebo explains.
The Norwegian model – There are challenges and opportunities ahead in implementing the suggestions, he admits. It will require effort on part of all parties involved. – IOR decisions are often time critical, he continues. However, he finds the Norwegian model of collaboration between industry and trade unions very useful. – It is time consuming, but you gain a lot when decisions are made—and it is a means to stay competitive.
FACTs
konkraft’s recommendations Initiatives are suggested in these areas:
»»Technology/R&D and piloting »»Reservoir characterization and modeling »»Managed pressure drilling (MPD) »»Enhanced Oil Recovery measures (EOR) »»Standardized contracts »»Drilling facilities »»Standardized procedures and equipment »»Cost efficiency and continued improvement »»Life-time costs »»ROI and regulatory issues to increase predictability in decision-making.
»»Subsea implementation, including maintenance and modification (MMO). This also entails establishing a task force to identify pros and cons of different MMO models.
The Subsea Future is All Electric The drive to convert hydraulic subsea applications to electricity, with all the benefits this would mean for many oil and gas fields, has gone on for many years. Oceaneering Subsea All Electric is at the forefront of this progress with cutting edge products and solutions. Oceaneering Subsea All Electric’s product portfolio meets the expectations and signal the oil industry requires for future subsea systems; Expanded use of electric sensor equipment and electric valve actuators. Infrastructure for under-ice and ultra deep water applications are challenging.
The efforts are focused on Subsea Electrical Actuation, distributed electrical subsea power, and inductive-contactless-galvanic sealed connection of power and communication. As future offshore developments will be dominated by subsea solutions in deep water, we know we are moving in the right direction: Subsea All Electric!
Benefits of “All Electric” Using the “All Electric” subsea technology will reduce the response time dramatically and produce higher control accuracy. It provides increased opportunities for acquisition of control data for monitoring the status and condition of subsea equipment. Systems can be used without hydraulic umbilicals which provides huge opportunities for cost savings and increased efficiency. No hydraulic also means zero environmental spill. Oceaneering Subsea All Electric is well prepared and ready to contribute to the future of all electric subsea fields. For further information about subsea all electric equipment please visit: www.oceaneering.no
3Stab
Subsea Power Bank system The Subsea Power Bank system is a distributed power and control Anti Surge Actuator system. It is the cost effective way of extending instrumentation of The Anti Surge Actuator (ASA) is a your existing subsea installation. High End Electrical Linear Actuator The system have multiple with built in Fail Safe Spring and canNorway be hooked-up Package for accurate operation Jåttåvågen, Hinna - P.O.Box 8024 -connections 4068 Stavanger, to, and communicate through, the and positioning of 82 Subsea Phone: +47 51 51 00Linear - www.oceaneering.no existing subsea control systems. Control Valves.
This is a connector for easy and reliable connection/ disconnection of ROV Tools and Subsea Equipment where hydraulic energy, electrical power and communication are required or desired
www.oceaneering.no
insight / flow assurance
NEW THINkINg, TEcHNOlOgy AND SAFER SySTEmS As oil and gas production moves further north and into more vulnerable areas, the focus on safer equipment and systems is getting even stronger.
s
INGER LISE WELHAVEN, redaksjonen@broddcom.no
ubsea systems and pipelines on deeper ground and through longer distances require new thinking, new technology and safer systems. Over the last years oil and gas production has moved from big traditional platforms to subsea installations. Per Gerhard Grini, chief researcher in Statoil and leader of the OG21 expert group of “Future technologies for production, processing and transport”, explains: – We are moving into areas with deep and ultra deep waters and harsher environmental conditions with strong winds and high waves. In the arctic there are long distances to shore lines and interaction with ice. In exploring more challenging regions, we require technology that secures safer operations.
PHOTO: CMr
In the forefront Leading the development of long distance multiphase transport projects like Tyrihans oil-dominated multiphase transport, Snøhvit’s gas condensate transport and the heavyoil solutions being employed at the Peregrino field, Statoil has put the company in forefront of the development regarding flow assurance and multiphase flow. – We are working to extend our NCS experience to offshore operations worldwide through development of direct electrical heating methods, hot tap and flow line technologies and extending simulation capabilities of advanced pipelaying, Grini states.
32 / brodd communication - july 2012
In exploring more challenging regions, we require technology that secures safer operations. Per Gerhard Grini, chief researcher in Statoil
New methods required Instead of being shut down, older platforms continue their operations today through the connection of subsea installations. That requires new methods of assuring technical standards . We achieve this through an increased number of inspections and by measmeas uring constructions, pipelines and processing equipment, according to Magne Husebø, technology director in Christian Michelsens Research. – In addition to flow assurance there is a need for more complex subsea integrity management as the current situation represents a lack of models, analyzing tools and sensor technology. Tomorrows subsea wells and processing systems will be equipped with a broad specter of sensors surveying wear and tear and other conditions of concern. In areas with colder water and bigger depths it will be difficult, if not to say impossible, “to clean up the mess” when the accident or leakage has occurred and the damage is a fact. Therefore, operating in these vulnerable areas gives the industry only one option: zero emissions, states Husebø.
Main challenges in Flow Assurance 01 LONG dISTANcES With pipelines over long distances on the seabed, the surrounding temperatures may impact the temperature of the fluid mixture.
02 REducEd TEMPERATuRES With reduced temperatures, hydrate and wax crystals may form which again may potentially block pipelines during shutdown scenarios. Under certain conditions, the wax crystals may bond in networks to form a gel. A research project in norway is currently developing new models for wax breakdown so that one may be able to model the restart process of a blocked (gelled) pipeline.
/ insight
Q&A HARdER THAN ROcKET ScIENcE
Johan Kristian Sveen, Project Manager of IFE and FACE.
– Flow Assurance has been a key area for Norwegian engineering companies for more than three decades. It all started with Olga, who is still alive and developing, says J. Kristian Sveen, Project Manager of IFE and FACE.
»»How has Norway managed to be in
the forefront of this development, Kristian Sveen? – Olga, the market leading software for Flow Assurance, was invented in 1980 by IFE and has been developed over 32 years with the cooperation of both international and national oil companies in addition to other national research institutions. Both Olga and the main competitor LEDAflow are programs of the Norwegian Flow Assurance Cluster and examples of what can be achieved by working with Norwegian research institutions.
»»Where is the main focus on current
03 MIxING OF SEVERAL WELL STREAMS Smaller satellite fields tied in to a larger facility may introduce additional challenges in the form of chemical and physical incompatibilities between the streams. The phenomena of one stream consisting of water with dispersed oil droplets, and another of oil with dispersed water droplets with the added complexity of surfactants, not to mention the presence of gas and sand, is extremely complex.
04 SuRFAcTANTS Surfactants tend to migrate to the interface between oil and water and may stabilize emulsions. This may have significant impact on both the transport and subsequent separation of oil and water. A good illustration is vinaigrette, consisting of olive oil and vinegar. Under normal circumstances these will separate easily.
However, if you add mustard powder, the mixture may stabilize because the mustard acts as a surfactant and migrates towards the oil-vinegar interfaces. Normal crude oils are significantly more complex than vinaigrette.
05 ASPHALTHENES This is one of a large number in a crude oil composition, and are relatively complex molecules. Combined with other parts of the composition, such as resins or waxes, the surface chemistry of crude oils is still an area needing more fundamental research.
06 SANd Sand is a general problem worldwide. Almost all crude oils are mixed with some sand and this may lead to corrosion and severe damage to the pipeline.
developments? – Multiphase flows in general are extremely complex, and the modeling of pipeline transport over kilometers of distance requires that the models are simplified. The main focus is now on improving existing models, to incorporate more of the physics of the real flow. This research field is incredibly difficult. We are not dealing with rocket science - Multiphase Flows are much harder than that! – The multiphase flow models used in Flow Assurance today are to a large extent based on simplified models. These models do not consider the effect of surfactants that are constituents present in most crude oils and tend to migrate to the interface between oil and water. This process may stabilize emulsions which may have significant impact on both the transport and subsequent separation of oil and water.
brodd communication / 33
insight case / flow assurance
mODElINg OPTImIzES AND REDUcES RISk IN FUTURE PRODUcTION
LAB TESTING. Peter Anderson at insitute for energy Technology is watching one of his experiments at the lab. PHOTO: iFe / MiKe TULLey
Flow Assurance modeling has increased the ability to tie in smaller satellite fields to larger facilities. however, new discoveries far from shore and in deeper waters challenge current models.
T
o ensure safe transportation in future pipelines it is of extreme importance to understand how the oil or gas act and react under conditions such as ultra deep or colder waters with lower pressure. – To do this one has to go down to micro and even nano level, says Johan Kristian Sveen, Project Manager of Institute for Energy Technology (IFE) and Multiface Flow Assurance Innovation center (FACE). – Surfuctant behavior at nano and micro scale directly impact macro scale behavior such as transport in pipeline and subsequent separation. Each oil or gas field is dif different when it comes to the product itself. Even oil coming from wells in the same re-
34 / brodd communication - july 2012
gion and connected to the same production platform can be of different quality and composition, making it important to be able to predict mixture behavior or avoid co-mixing altogether, Sveen explains. The challenging location of many of the recent field discoveries has required a need to improve the models for vertical flow in long risers and wells and over long distances on the seabed. With reduced temperatures, hydrate and wax crystals may form and potentially block the pipelines during shutdown scenarios, and presently a large focus is put on these issues.
Real time measurement At the moment numerical models may simulate process equipment in 3D and time. However, the measurement technologies for laboratory and field have not enjoyed the same leaps in development. Sveen sees a need for radical change in sensor technology capabilities. – Real time measurement improves our
predictive models and our general understanding of flow assurance issues. This leads to robust multiphase flow measurement which may significantly impact field operations and ultimately enable production optimization, he says. Magne Husebø, Technology Director at Christian Michelsen Research AS, emphasizes the need for sensor technology. – Next generation complex subsea processing and long distance transport systems require new sensor technology for the overall operation management. Condition monitoring based integrity management will, alongside real time sensor input to model based flow assurance, be the back-bone for safe and reliable subsea operation, Husebø states. This is a priority area for Christian Michelsen Research and the industry owned UPTIME Centre of Competence, through the establishment of “Real-Time Risk Management” as a methodology for maritime and offshore operation and maintenance.
Together with the industry, CMR aim to fulfill the new OG21 strategies. Christian Michelsen Research AS hosts the UPTIME Centre of Competence. The industry-owned centre is focusing on innovation and entrepreneurship within maritime and offshore operation and maintenance.
cmr.no
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news / subsea power
The power of connectors Electrical machines for subsea processing operating at the bottom of the sea are dependent upon a reliable supply of electric power. The insulation failure of critical connecting components could cause a cease in production.
O
PIA PEDERSEN, redaksjonen@broddcom.no
ne of the biggest challenges for subsea electrical connections is water ingress and an eventual breakdown of insulation. For land installations, the connections to e.g. transformers or motors are normally straightforward, standing next to the component during installation. For subsea installations at the seabed, remotely operated vehicles (ROV’s) are needed. Senior researcher at SINTEF Energy Research, Sverre Hvidsten, says that avoiding water ingress during connection and operation is crucial. – The equipment can be operated under extremely high hydrostatic pressure and it’s challenging to avoid water entering the system during installation at the seabed. Although the experiences with the subsea power systems in operation are generally good, electrical failures are often linked to bad connectors. A worst-case scenario is a power outage due to a connector failure stopping pumps and compressors used for subsea processing. That would be dramatic, says Hvidsten.
which increases the temperature. It’s challenging to make sure that the components can withstand these demanding environments, says Hvidsten.
Research on how to make the electrical components work better under extreme conditions is becoming essential.
Extremely important To ensure a reliable supply of energy to offshore and subsea installations, the service performance of the electrical components is extremely important. – We have, within a large research programme, built a subsea laboratory that is quite unique. What’s particularly innovative is the possibility of performing tests at high voltage, high pressures and temperatures simultaneously. We are able to make electrical tests up to 1000 Bar equivalent to a water depth of 10 000 meters. Using this facility we can find the best materials for e.g. connectors and penetrators and study how they function at high temperatures and under high pressure. I’m confident that we’ll find the best solutions to ensure smooth operations in demanding environments, says Hvidsten.
FACTS
Higher demands Because an increasing number of oil fields are located at longer step-outs and in deeper waters, the demands on electrical components are getting higher. SINTEF Energy Research has several clients that are interested in research enabling the transmission of higher voltage and more power at even higher water pressures. – Researching how to make electrical components work better under more extreme conditions is becoming essential. Equipment is now being placed in deeper waters where it is submitted to higher pressure. High voltage equipment is also placed closer to and even inside the actual well,
36 / brodd communication - july 2012
factoid: power outages during 2011
»»In 2011, a total of 12 power outages were documented on platforms on the Norwegian continental shelf ranging from less serious to acute/critical.
»»The most serious outages on Sleipner B and Alvheim
Sverre Hvidsten, Sintef
FPSO lasted 20-30 minutes but production ceased for longer periods due to evacuation of personell and not knowing the root cause. Fire was initially reported on Sleipner B. However, later the cause of electrical failure actually turned out to be a node error in the B&G system.
Source: www.petro.no
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Subsea Laboratories Research relevant for new offshore oilfield development with the ephasis on Increased Oil Recovery (IOR) requiring reliable, compact and efficient subsea installatios and components. Main applications • Ageing and qualification of materials and components • Characterization and testing Pressure vessels • From 0.08 to 2000 litres • Up to 1000 bar (dependent of size) • Temperature control -20 °C to 200 °C • Voltage 0 to 150 kV Contact: Petter.E.Rokke@sintef.no
Technology for a better society
insight / increased- and enhanced oil recovery
Great Potential for Increased Recovery on NCS NCS continues to be a world leader in oil recovery. While the global average is about 36 percent, the NCS average is now 47 percent. Nevertheless, operators on NCS are aiming even higher. GUNN IREN KLEPPE, redaksjonen@broddcom.no
A
recovery factor of 47 percent at the end of field life, still means 53 percent oil left in the field, says Erik Skjetne, OG21 Leader for Exploration and Increased Recovery (TTA2) and Leader of Subsurface Business Development and Innovation at Statoil. At present, there is about 46 percent immobile and 54 percent mobile oil left in Norwegian fields in production. Mobile oil can be recovered mainly by drilling more wells in each reservoir. Immobile oil, however, cannot be recovered using standard water and gas injection. – It is a different game, he argues.
Need for innovation The 90s saw an increase in the recovery fac-
FACTS
some recovery facts
»»TTA’s goal is to «develop new technology to
add 7.7 billion bbl o.e. recoverable resources and reserves, including exploration technology.»
»»NCS average recovery factor for oil has flat-
tened since 2004. Smaller oil fields hold the same average factor of about 30 % as in 1992. Larger fields have increased from 35 to 50 %.
»»Subsea compression on Midgard should bring the recovery rate from 69 to 86 %.
Source: TTA2
38 / brodd communication - july 2012
tor, and most fields have larger reserves than initially estimated. – On average 68 percent, he adds. However, the recovery factor has since flattened and new technologies are needed to spur another increase. NCS has been a driver in advanced geo- and reservoir modelling worldwide. New developments include a tighter and faster integration of advanced geo-modelling, 4D seismic reservoir monitoring and dynamic reservoir simulation, where history matching is used to predict future production. Good models are crucial to optimize well location in complex or depleted reservoirs.
Still potential – Water injection has given rise to enormous value creation, Skjetne points out. Ekofisk, for example, initially had a 17 percent recovery factor without water injection. Today the goal is 50 percent and higher. – We know that new technology works. However, many methods that we know work very well onshore, have yet to be implemented offshore, he explains. Enhanced Oil Recovery (EOR) goes beyond standard gas and water injection, typically involving chemicals added to water or gas based methods like CO2 injection. – If the price of oil remains high, there is still a great potential for further improvement. We need new—and more efficient and environmentally friendly—chemicals as well as improved reservoir simulation to reduce uncertainty and justify the high cost of new recovery methods, he concludes.
PHOTO: FMC TECHNOLOGY
EOR & IOR methods EOR – MOBILE OIL
»»Polymer water flooding: increases water vis-
cosity. Used extensively onshore in China. Several oil companies are doing or preparing for offshore field tests. »»Deep water diversion: forces water to find new paths. Under field testing, not yet implemented on NCS. Used extensively onshore in China. »»WAG: alternating water and gas used fairly extensively on NCS. Foam: reduces gas mobility, postponing gas breakthrough in oil producing wells. Field tested.
EOR – IMMOBILE OIL
»»Miscible gas injection: high pressure
/ insight
Q&A INNOVATION AND TRENDS
Erik Skjetne, OG21 Leader for Exploration and Increased Recovery (TTA2).
»»Your thoughts on new trends and the
need for innovation? – One very important technological development on NCS was the use of horizontal wells and later multilateral wells. Now there is a need for new offshore well design in low productivity zones. Statoil currently has an average offshore recovery factor on NCS of 50 %. The company is eager to raise the bar higher, so Statoil is planning a new Increased Oil Recovery research laboratory in Trondheim to bring oil recovery to the next level.
»»What are the challenges?
gas injection gets out almost all the oil.
»»CO2 injection: not yet tested on NCS, good
results expected. Modifying existing oil platforms is very costly. Used a lot onshore in the US. »»Low salinity water injection: used instead of sea water to modify oil-rock interaction. A couple of field tests completed on NCS. Relatively low cost and good in combination with other methods due to reduced chemical consumption. »»Surfactant flooding: fairly well tested, quite expensive. Reduces oil/water surface tension. Oil recovery up to 98 percent in core floods. Needs fine-tuning. »»Microbial EOR: bacteria produce soap, reducing oil/water surface tension. Used for extended time at Norne. Record subsea
field recovery 60 percent, though MEOR effect hard to estimate.
IOR & PRoduction optimization – Mobile oil
»»Reservoir characterization combined w/4D
seismic to locate remaining oil. Sea-floor embedded fibre-optic listening cables provide further seismic enhancement. »»Infill drilling—new wells in existing oil fields. Current most common method for increased mobile oil recovery. »»Advancedwellsolutions: choking inflow of water/ gas in long, horizontal (or multilateral) wells. »»Subsea gas compression: adds pressure, increases production. Method approaching maturation, ready for field testing. High cost, high potential.
– The difficulty with new recovery methods is that field tests are extremely costly. Including field modifications, a field test to fully qualify a new method may cost in the range of 16.5-165 million USD. However, a greater change in drainage strategy is often needed to get a large increase in recovery. Initially, oil production on Troll was not believed possible nor was water injection at Ekofisk. Increased recovery is very much about decision making. Changing the drainage strategy of a field typically involves large capital and operational expenditures. The decision maker wants to be sure that huge costs are justified by added oil production. Therefore, some of the technology that needs to be developed is to reduce uncertainty in predicting the effect of new recovery methods. There are two main paths; to reduce uncertainty and increase effect.
»»Anything else of interest?
– Quite a few smaller Norwegian hitech firms are doing quite well internationally. They will play an important role in future innovation. In fact, some UK industry representatives say they consider NCS to be more open to innovative solutions than the UKCS.
brodd communication / 39
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development of the norwegian continental shelf / insight
Delivering technology the world needs Development of the Norwegian continental shelf has advanced technology and expertise putting production of oil and gas in Norway at a world class level in both extraction and energy efficiency. These technologies and services have become Norway’s largest and foremost exports. RUNAR RUGTVEDT
HEAD OF OIL AND GAS AT THE FEDERATION OF NORWEGIAN INDUSTRY
P
etroleum resources on the Norwegian continental shelf have created a basis for a highly competent and internationally competitive oil and gas industry. Oil companies, suppliers in collaboration with research and educational institutions have found solutions to demanding conditions at sea. Large, complex development projects have forged new technological solutions. Strict demands for energy efficiency and air and water emissions have produced world-class technologies and products. The past decade, Norwegian suppliers have exploded onto the international market. Norwegian suppliers dominate the market of drilling technology and the market in subsea production and processing systems.
Globalization and the supplier industry The globalization of the Norwegian supplier industry has accelerated the past two years. Large Norwegian corporations, such as Aker Solutions and Aibel, have built significant networks and technology environments in both Europe and Asia. This gives them access to cost-effective resources as well as close proximity to interesting markets. From a Norwegian perspective, it’s important that this core expertise from the tech sector and suppliers is not only developed in Norway but also stays in Norway. Here, it’s important that the authorities, together with industry professionals, accomplish this through competitive university studies. Devel-
oping research environments in businesses, at universities and in research institutions will attract both Norwegian and foreign workers.
High demand and steady activity A continued high commercial demand on the Norwegian continental shelf is crucial for the future of many businesses and employment throughout the entire country. This concerns not only businesses and jobs in oil companies and in the petroleum targeted supplier industry but also other companies connected to the industry. Investment prognoses for the next 5-10 years are steadily climbing. Next year, investment on the Norwegian continental shelf will reach a record high of NOK 190-200 billion.
Access to new areas It’s important in the long-term to continue to uncover new resources to secure steady and high production and activity on the continental shelf. Without available areas, the demand for the supplier industry will dwindle according to reduced findings on the continental shelf. This, in turn will result in a diminished need for Norwegian based suppliers. Access to promising exploration areas is critical to establishing new and bigger projects that will help develop future technological solutions.
Expertise and transfer of technology Expertise and technology from the petroleum industry gives synergies for other related industries. Kværner Verdal has, for example, ac-
quired significant contracts for the production of suspension for offshore windmills. Nexans in Halden and Parker Scanrope in Tønsberg deliver underwater electrical cables to windmill parks in Europe. Aibel and ABB have been awarded contracts worth billions building converter stations for these windparks. In the same manner that knowledge and experience from shipping was important for the development of the supplier industry in the petroleum industry, today’s knowledge base supports future activity within renewable energy.
New technology New technology and innovative solutions are necessary for the development of new, profitable reserves and extracting the large potential in the increased development of the Norwegian continental shelf. There needs to be an increase in goal-oriented research, as well as pilot programs like Petromaks and DEMO 2000. It’s critical that strategic areas of research and technology, pointed out by the industry by, amongst others, OG21, are on the forefront for future initiatives.
It’s important in the long-term to continue to uncover new resources to secure steady and high production and activity on the continental shelf. Runar Rugtvedt
brodd communication / 41
news / expertice
Making brave decisions Expertise is always crucial, and especially when the system fails, says Norwegian Veritas’ Chief Operating Officer and Executive Vice President, Knut Ørbeck-Nilssen. But equally important is the ability of management and employees to make decisions. SYNNE HEDLO, redaksjonen@broddcom.no
»»What kind of expertise does a company need to have
in place in order to make oil and gas production safe? – When it comes to risk management, the important thing is that employees and leaders have deep operative knowledge, so-called hands on experience. – During any kind of system failure, obviously expertise is important, but it’s not the only factor. It’s also important to make brave decisions. We have to be creative problem solvers while weighing the risks.
»»can you give any real world examples? – A classic example is Roald Amundsen’s South Pole expedition. Solid planning and good routines, meaning the right expertise, contributed to the expeditions success. But equally important was making difficult and potentially fatal decisions during the expedition itself. The accumulated knowledge and experience of the groups members insured that the right deci-
When it comes to risk management, the important thing is that employees and leaders have deep operative knowledge, so-called hands on experience. experience
sions were being made. The result is well known and celebrated. Sadly, Scotts expedition, on the other hand, had a tragic outcome.
»»Incentives that reward employees who score well on
safety are controversial. The suspicion has been that this model can lead to lacking safety measures being “brushed under the carpet”. Is the incentive-model ripe for discussion? – Issues regarding safety should be an ongoing discussion. Not only for the sake of reaching todays optimal safety standards, but because this keeps the issue of safety continually in focus,in turn leading to advances applicable to an ever changing industry. With each generation, we learn more.
»»What is the best way of rewarding high safety standards? Knut Ørbeck-Nilssen, Norwegian Veritas’Chief OperatingOfficer
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A few other projects where Devotek has contributed actively are
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Circulate fluids with the rig pumps. A large number of small diameter laterals jets out from the wellbore to penetrate the reservoir. You will spend less than half a day of rigtime on an operation that does not require additional fluids or pumps. And you even get better productivity than traditional hydraulic fracturing operations in many cases.
Fishbones operations are simple; Run the reservoir liner string as normal and set the liner hanger slips.
Fishbones can be used with acid for jetting of carbonates or with non-reactive fluids for other formations.
DESTINO
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