Latest Oil and Gas News Russia

David Bamford

Much is made of the fact that the oil & gas resources of our planet will last many more decades: this is evident if one digs into the most recent BP annual Statistical Review of World Energy. It is also true that much of this petroleum still needs to be found, whether in new discoveries or upgrades of existing discoveries or increases in the recovery factor of currently producing fields or even in the resurrection of currently abandoned fields.

Finding Petroleum in the future will take us to tougher areas, more complex geology, more difficult reservoirs and, unless we are very smart, much higher Finding Costs. It would be wrong, ironic and a great shame if, as companies increased expenditures coming out of the current downturn, they find less barrels and molecules due to tough problems and rampant oil field service prices!

In currently producing fields, this translates into inventing the most efficient and effective way of finding additional petroleum. After all, there is an old adage which says "the best place to look for petroleum is in a producing field!"; in technical terms, this equates to increasing ultimate recovery factors from where they might be perceived to be today, say 25-30%, to 60 or even 70+%.

In my opinion, for many oil & gas companies the best way to do this will be to simply adopt The Digital Oil Field in all its aspects. For some excellent insights into this concept, I refer you to a presentation by David Latin of BP. You can also find a detailed description of BP's Field of the Future concept on the company's web-site.

However, there is a risk that in the current economic climate, installation of a Digital Oil Field, entailing heavy upfront capital expenditure for long-term operating benefit, may be seen as an expensive luxury. This is an understandable if not entirely sensible view point: we are in "Hard Times", not because oil & gas prices are desperately low but because the lesson we have learned from the volatility of the last 12-18 months is that future oil & gas prices are desperately uncertain.

Nonetheless, the right question is – how do we dramatically reduce the costs of the Digital Oil Field so that installation makes sense at (almost) any oil or gas price?

Let's focus on one of those technologies that is especially relevant to the recovery factor question, namely seismic monitoring. How could we ensure that it makes economic sense to shoot 3D seismic - and repeat 3D, also known as 4D - on any producing oil/gas field in Russia and the FSU? Drawing on lessons from the proliferation of 3D seismic technology in the 1990's, the key seems not to attack prices directly but to focus on significant reductions in cycle-time, that is, the time between planning a survey and obtaining a useful sub-surface interpretation that finds areas of un-swept petroleum. In other words, faster led, and will lead, to cheaper and better.

It seems pretty clear how not to do this. Old-fashioned onshore acquisition techniques, involving cutting swathe after swathe through the tundra or the wheat fields and armies of men lugging vast quantities of cable around, up mountains, across roads and rivers, through swamps, seem like - and should be - a thing of the past, on efficiency, effectiveness and HSE grounds. Likewise, ultra-high-resolution techniques - no matter how unique their inventors might think they are - do not seem to be the way forward either, although it would be interesting to see authenticated cycle-time and cost/sq km comparisons published, perhaps on the InterNet.

Instead, we should be looking to the wireless, cable-less systems on offer from ION, OYO Geospace or iSeis, and the innovative approach to sources advocated by Ian Jack.
I have documented evidence from the previously mentioned offshore 3D history that an intense focus on doing things faster will lead to cheaper (dramatically reduced unit costs), in turn meaning that many more, bigger, 3D surveys will be commissioned.

Contractors should therefore see this as a golden opportunity to take part in the dramatic growth of onshore 3D and 4D rather than as a threat to their established systems.

Labels: digital oil field, Russian oil gas news

posted by The Rogtec Team @ 14:33  1 Comments

TNK-BP and Weatherford International Ltd. (NYSE: WFT) today announced that Weatherford has agreed to acquire TNK-BP's Oil Field Services (OFS) enterprises in exchange for 24.3 million shares of Weatherford common stock and other consideration.

The transaction remains subject to approval from Russia's Federal Anti-monopoly Service.

TNK-BP's OFS business currently provides drilling, sidetracking, well intervention and workover, cementation and required support services in Russia. It comprises six operating companies owning and operating more than 75 drilling rigs, 180 workover units, 150 cementation and pumping units and over ten operating bases in critical reservoir plays including two central bases in Western Siberia and the Volga-Urals region. OFS revenues exceeded $650million in 2008.

OFS benefits from TNK-BP's considerable investment in productivity over the last five years, upgrading rigs and infrastructure, extensively training personnel, and developing business systems and processes. Weatherford's long term commitment and the combined company's local management and staff will accelerate the introduction of new technology and ensure continued productivity growth of oilfield services in Russia.

TNK-BP and Weatherford expect to benefit from a preferred customer/supplier relationship in which Weatherford provides drilling, well intervention and workover services, cementation and other advanced oil field technology. The deal will enhance the productivity of existing drilling and workover services available to TNK-BP's exploration and production teams.

"This transaction with Weatherford allows us to drive further efficiency into our business in today's testing economic climate, and will give us access to the world's most technologically advanced rigs, drilling and work-over equipment and services. It will also secure jobs and boost investment in Russia's services sector generally," said Tim Summers, Chief Executive Officer of TNK-BP.

Bernard J. Duroc-Danner, Chief Executive Officer of Weatherford, commented "This investment in Russia's oil industry and its future growth strengthens Weatherford's position in one of the most important global oilfield service markets. The acquisition of quality infrastructure and highly trained staff provides a conveyance capability that complements Weatherford's existing product technology and service capability in Russia. The combined company will provide customers with a primary service competency in development drilling and production enhancement."

TNK-BP is Russia's third largest oil company, 50% owned by BP and 50% owned by AAR (Alfa, Access Renova). TNK-BP's shareholders also own close to 50% of another Russian oil and gas company, Slavneft. TNK-BP accounts for approximately 16% of Russia's production (including its share of Slavneft). SEC proved reserves (life of field basis) were 8.112 billion boe as of December 31, 2008. The company's upstream operations are located in West and East Siberia and the Volga-Urals region. TNK-BP owns and operates five refineries in Russia and Ukraine, and retails through a network of 1,100 service stations working under the BP and TNK brands.

Weatherford is a Swiss-based, multi-national oilfield service company. It is one of the largest global providers of innovative mechanical solutions, technology and services for the drilling and production sectors of the oil and gas industry. Weatherford operates in over 100 countries and employs over 45,000 people worldwide.

Contact: Andrew P. Becnel +1-713-693-4136 Chief Financial Officer

Nicholas Gee +1-713-693-4017 Vice President Investor Relations

This press release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 concerning, among other things, Weatherford's prospects for its operations which are subject to certain risks, uncertainties and assumptions. These risks anduncertainties, which are more fully described in Weatherford International Ltd.'s reports and registration statements filed with the SEC, include the impact of oil and natural gas prices and worldwide economic conditions on drilling activity, the outcome of pending Government investigations, the demand for and pricing of Weatherford's products and services, domestic and international economic and regulatory conditions and changes in tax and other laws affecting our business. Should one or more of these risks or uncertainties materialize, or should the assumptions prove incorrect, actual results may vary materially from those currently anticipated.

Labels: buyout, Oilfield Service (OFS), Russian oil gas news, TNK BP, Weatherford

posted by The Rogtec Team @ 09:28  0 Comments

V. N. Manyrin, R. Sh. Mufazalov (Russian Society of Oil and Gas Engineers, Moscow, Timurneftegaz Research and Production Company, Oktyabrskiy)

Problem number one for all oil producing regions is preserving the potential productivity of a bed during the drilling-in process. This problem is especially topical for mature fields, fields with low formation pressures, and fields containing highly viscous oil. Therefore, the most critical stage in well construction is good, clean penetration of the producing (oil-bearing) horizon, since the initial flow rate, the duration of effective well operation, and the oil recovery factor during field development are completely dependent on the cleanness and quality of the penetration.

Due to the special importance of the drilling-in phase during well construction or workover, these operations are performed by specialized teams in many foreign oil companies.

Causes of Problems
The current and widely used methods for drilling-in and completion are far from perfect from both the technical and technological viewpoints. In the majority of cases, they do not provide the best productivity index and oil recovery factor, especially in poorly productive reservoirs and fields in the late stages of production.

During initial drilling-in, the solid, fine phase of the drilling mud, cuttings, mud globules, and crystals of weighting agents and polymers penetrate the pores and cracks in the reservoir simultaneously with the filtrate. The penetration depth of the filtrate is several times greater than the depth of the perforations, and this is the primary cause of degradation of oil inflow into a well. This is generally the result of a mismatch of the physicochemical properties and rheological parameters of the drilling mud, as well as imperfections in the hydraulics program and the drilling-in conditions.

In its natural state, a reservoir is under uniform compression by rock, hydrostatic, and geostatic pressures. The natural pressure conditions are disrupted during drilling-in, with deformations and the onset of shear stresses. These stresses sometimes exceed the rupture strength of the rock, especially where the rocks are anisotropic and have differing values of elasticity, rupture strength, and volumetric expansion. The anisotropy leads to asymmetrical deformation stresses, primarily in the borehole environment, and fractures and cavities in areas where stresses are concentrated. Deformation anisotropy of the porosity and permeability occurs. This is the next cause of reduced inflow.

The problem is aggravated by the fact that penetration of the solid particulate phase by drilling mud filtrate and deformational changes in the reservoir occur simultaneously as it is penetrated, causing irreversible processes such as pinch-off and plugging. Carbonate reservoirs are the most sensitive to deformational changes due to their fissuring.



Analysis of Experience in Use of Technology
In recent years, searches for new methods for intensifying the drilling process and improving well flow rates have led to nontraditional methods for bottomhole zone treatment during the drilling and oil production process.

To solve this problem, specialists at Timurneftegaz Research and Production Company have developed reactive acoustic equipment and technology for drilling and penetration of the producing horizon of a well, and have obtained patents for this invention (1). The patented design comprises a drill bit with a reactive acoustic module. The use of this equipment and technology reveals fundamentally new approaches to solving this problem, and experience in drilling in various fields and regions has produced the following positive results:

• the rock boring efficiency is increased, and the drilling rate is increased by 40% to 90%;
• the service life of the drill bit in the well is prolonged and the headway per bit is increased by 50% to 80%;
• the diametral wear of the bit, especially the calibrating elements, is reduced significantly;
• the drilling mud is subjected to undulation during drilling. is homogenized, and its rheological properties are improved as a result;
• a thin protective screen is created around the borehole wall that prevents penetration of drilling mud and grout into the producing and water-bearing beds and thereby prevents their contamination (cleanness of the reservoir is ensured);
• minor (up to 15 m3/hour) lost circulation in the drilling process is prevented, and the probability of gas, water, and oil kicks and formation fluid crossflow during drilling is reduced significantly;
• the formation of blockages above the bit, cave-ins, and sticking of the bit when drilling in unstable rocks is prevented, and the quality of the wellbore is improved;
• the friction on the drill string in horizontal and directional sections of the wellbore is reduced significantly and the required load on the bit is ensured;
• the reactive acoustic tension when drilling a horizontal section of a wellbore is comparable to the required axial load on the bit, and ensures that it is loaded smoothly;
• the time required to complete wells into producing beds penetrated using this technology is 1.5 times less than the standardized time, while the flow rate is 1.5-2 times greater than the flow rate from a bed penetrated using the conventional technology.

Influence of Hydroacoustic Field on Filtration Processes
In view of the special importance of the drilling-in process, the influence of the hydroacoustic field on the filtration of the flushing fluid through cores with various permeabilities was studied. (2). The results of the studies of mud filtration through core samples under static and dynamic conditions and in a hydroacoustic field differ. The essence of the differences is the change in the filtration rate over time, since the changes in the velocity and volume of the flushing fluid filtrate are the primary indicators of the formation of a protective screen, i.e., of the degree of colmatation of the borehole wall. Fig. 1 provides curves of the filtration (colmatation) rate during time under static (1) and dynamic (2) conditions and under a hydroacoustic effect (3).

The studies of the filtration processes showed that under a hydroacoustic effect the formation of a protective screen is accelerated by a factor of 10 or more, as a result of which the filtration rate drops to near zero after 15-20 seconds, and the degree of colmatation reaches 92-96%, while the volume of filtrate penetrating the bed decreases by several orders of magnitude.

This degree of colmatation is achieved in 50-60 minutes under static and dynamic conditions. A mud cake is present under static and dynamic conditions, while under hydroacoustic effects there is no mud cake, and the thickness of the protective colmatation screen is 10-18 mm in the pores of the core samples studied.

Furthermore, the decolmatation (cleaning of the pores under the influence of hydroacoustic waves) was also studied [2]. Under hydroacoustic effects on the cores, the colmatation layer is cleared tens of times faster, until the permeability of the rock is completely restored.



Hydroacoustic apparatus and technology for well completion and stimulation of the inflow from a producing horizon were developed on the basis of the studies (see pic 3 of hydroacoustic device for well completion).

In particular, hydroacoustic generators for drilling with various active elements (vortex, toroidal, disk, diaphragm and parametric generators) operating with output parameter amplification were developed. The amplitude-frequency responses of hydroacoustic generators under various operating conditions were studied to create hydroacoustic devices with the required parameters and to select the optimum design. This work was performed at the Russian Academy of Sciences Machinery Science Institute (IMASh) [3] and the regional enterprise OTO Production Ltd., with the involvement of specialists of the Machine Acoustic Institute of Samara State Aerospace University [4]. It was found during this work that the output parameters of these devices are dependent on many factors: the type and geometrical dimensions of the active elements, the density, viscosity, quantity and flow rate of the active agent in the pores, and the counterpressure in the system. However, the most important fact is that the waves generated are nonlinear hydroacoustic waves with simultaneous generation of frequencies from 0.15 to 16 kHz. Figs. 4 and 5 show the amplitude-frequency responses of hydroacoustic devices for well drilling and completion under various operating conditions.





Application of Technology
This technology can be used in the rotary drilling process using various downhole motors, including electric drills for directional and horizontal drilling with drill bit diameters of 124 mm and larger. The photographs show reactive acoustic modules for drilling directional and horizontal wells using drill bit diameters of 124.0 and 215.9 mm and a diagram of the operation of a reactive acoustic module in a horizontal borehole.

According to the results of test well drilling in the Zyuzeyevskoye field by Tatnefteprom (Almetievsk) performed to determine the effectiveness of various technologies for penetrating producing formations containing highly viscous oil, the best results in terms of the specific productivity of a formation were achieved using hydroacoustic technology.

In addition, test wells were drilled to assess the effectiveness of various well completion technologies under the conditions of the Tatneft oil fields.

Thirteen preferred technologies were used, including hydroacoustic penetration technology. The results of the test well drilling were processed and analyzed by the TatNIPIneft Institute. According to the criterion used, the best results in terms of formation penetration effectiveness were obtained using the hydroacoustic technology: the specific productivity was increased by a factor of 3.8.

In the opinion of specialists from Saudi Aramco, where 100% of the wells are horizontal wells, as well as per the horizontal drilling engineering support provided by Sperry-San, where the trial operations were conducted, the hydroacoustic technology simplifies drill string guidance and trajectory correction, improves accuracy, and accelerates drilling.






Primary Parameters of Reactive Acoustic Device:

• diameters of drill bits used: 124 mm and larger;
• flushing fluid density: 900-2200 kg/m3;
• permeability of rocks drilled: 0.001-2.0 u2;
• with lost circulation of up to 30 m3/hour and pore size of 10-8 m;
• in any type of reservoir and unspecified formation temperature and hydrogen sulfide content;
• hydroacoustic wave frequency: 0.15-16 kHz;
• pressure: 1.5-6.0 MPa;
• drilling mud consumption: 0.020-0.035 m3/sec;
• pressure differential in device: 3.0-6.0 MPa;

Overall dimensions:
diameter: 120-295 mm;
height: 350-800 mm;
weight: 20-150 kg

Conclusion
The results of the comparative analysis show that the reactive acoustic equipment and technology is unique and has no analogs in world practice in terms of its ease of use, reliability, effectiveness, and multifunctionality. The hydroacoustic technology is now the basis for developing a whole series of devices using its technological principles in the oil producing, petrochemical, and other industries. They are all superior to traditional technologies. The developers are protected by patents in the Russian Federation, the leading nations of Europe, the USA, Canada and Japan.

It should be noted that the hydroacoustic technology used in various processes is exceptionally environmentally friendly and physiologically safe, which is very important for its widespread use in the fuel and energy sector.

References
1. RF Patents for Invention No. 2270315 and 2351731.
2. R. Sh. Mufazalov, R. Kh. Muslimov, L. R. Klimov et al. Hydroacoustic Equipment and Technology for Drilling and Penetration of a Producing Formation. Kazan: Dom Pechati Press, 2005, 184 pp., illustrated.
3. Wave Technology and Equipment. Edited by Russian Academy of Sciences Academician R. F. Ganiev. Moscow, Logos Press, 1993, 127 pp., illustrated.
4. Technical Report of Machine Acoustic Institute of Samara State Aerospace University under Contract No. 019 dated March 12, 2001 "Measurement of Amplitude-Frequency Responses of Downhole Generators".

Labels: Acoustic technology, Reactive, Reservoir Penetration, ROGTEC, Russian oil gas news

posted by The Rogtec Team @ 17:33  2 Comments

NEWS

Lukoil technique recognized as one of Russia's best inventions
LUKOIL specialists were awarded a diploma by the Federal Service for Intellectual Property, Patents and Trademarks (Rospatent) in the nomination "Russia's 100 Best Inventions". The diploma was awarded for RF patent No. 2335628 on invention of the technique for "local directional hydraulic reservoir fracturing at oil or gas fields".

The team of inventors includes: Dzhevan Cheloyants, OAO LUKOIL Vice President, Head of the Main Technical Division, Mikhail Vyatchinin, Deputy Head of the Main Division of Oil and Gas Production, Vladimir Titievsky, Head of the Division of Oil Production, Yuri Ikonnikov, Head of the Oil Production Section, and Robert Ramazanov, Head of the Oil Production Servicing Section.

The technique is aimed at production enhancement of oil, gas and gas-condensate fields and, particularly, of mature fields characterized by high water production and occurrence of lost-circulation and blind zones which are insusceptible to application of common production techniques.

Kamennoye Progress Pleases TNK-BP
TNK-BP says its Kamennoye field one of the oldest in west Siberia and only a decade ago widely viewed as impossible to develop - should soon provide a big boost to output growth. Development of the 2bn bl field in the Khanty-Mansiyisk district is one of three projects on which TNK-BP is focusing this year, the others being the Uvat and Verkhnechonsk greenfields. The firm says making crude extraction from Kamennoye economically viable was particularly challenging as the geology is more complicated than at any of its more recent developments.

Since 2004, TNK-BP has invested $600mn in Kamennoye and plans to invest $700mn more in 2009- 13, including $250mn this year.

Gazprom grabs 20% of Sakhalin-1 gas
The Sakhalin-1 consortium reportedly has agreed to sell 20% of the natural gas extracted from the project to Russian monopoly Gazprom. US supermajor ExxonMobil operates Sakhalin-1, on the Russian Pacific coast island of the same name, in cooperation with Russian state oil firm Rosneft, Japan's Itochu, Japanese outfit Marubeni and India's ONGC.

Gazprom has long said it needs the gas produced at Sakahlin-1 to cover domestic needs, while ExxonMobil has long-stated it is looking for the best price, though has eyed major importer China for some time. The project has been producing oil for several years and reached peak production of 11.2 million tonnes in 2007.

Roxi duo pass the test
Kazakhstan-based oil explorer Roxi Petroleum has successfully tested two wells in central Kazakhstan. The company said it estimated reserves of 13 million barrels of C1 and 5 million barrels of C2. Roxi said the average daily test production from the NW Konus field is 1000 barrels of oil per day.

Russia and Serbia prime gas pact
At the time of going to press, Serbia's gas monopoly Srbijagas and Russia's Gazprom were expected to sign a agreement, to develop an arm of the South Stream gas pipeline. The deal, will allow Serbia to diversify its gas supplies and avoid shortages.

"The Serbian arm of the pipeline will have annual capacity of 20 billion cubic metres of gas and will be about 450 kilometres long," Bajatovic told the news agency. Last December, Serbia and Russia finalised a bilateral energy pact, with Belgrade agreeing to sell a 51% stake in its oil monopoly NIS to Gazprom Neft for $400 million ($544.6 million) in exchange for an arm of the South Stream gas pipeline and the completion of the Banatski Dvor gas storage.

The South Stream has been designed to bypass Ukraine and transport Russian gas under the Black Sea to Bulgaria and onwards to Serbia and Europe.

Nabucco engineers get to work
Nabucco pipeline engineers have begun detailed planning along the gas route between the Caspian region and Europe, taking the project into its next phase, the Vienna-based consortium announced. The consortium's engineers in Austria, Hungary, Romania, Bulgaria and Turkey will help prepare for negotiations with gas suppliers and enable local approvals for the project, which plans to pump gas through 3300 kilometers of pipeline from 2014.

The project has gained impetus following the gas price row between Russia and transit country Ukraine in January, which left over a dozen European countries without gas for two weeks. But funding, the sourcing of natural gas and some disagreement between consortium members have also weighed on the project, which has had to push back some of its target dates, a Reuters report said.

The European Union's agreement in Prague last week to smooth the way for more gas imports from the Caspian region was an "important political milestone" for the project, consortium head Reinhard Mitschek said in a statement.

TNK-BP Appoints Executive Vice President, Technology
TNK-BP announces that Francis Sommer has been appointed Executive Vice President, Technology of the TNK-BP group of companies.

Francis has been with TNK-BP since 2005, as Vice President, Technology. He has played an important role in technology transfer to TNK-BP, and has been instrumental in establishing a consistent approach to the evaluation and quantification of reserves across TNK-BP's asset base. He joined TNK-BP following a successful and varied petro-technical career of almost twenty years in BP, in the UK, USA and Colombia.

Japan and Russia to co-develop oilfields
Japan and Russia plan to sign an agreement, as early as today, to jointly develop oilfields in Eastern Siberia. It has been reported that the agreement will involve two oilfields in central part of the Russian region of Irkutsk.

The project will be led by a joint venture between Japan Oil, Gas and Metals National Corporation, or JOGMEC, and Irkutsk Oil. The Japanese government-owned company is expected to take a 49% stake and the Russian partner the remainder. With the goal of starting full-scale production as early as 2013, the joint venture will kick off survey and drilling in 2010 or later.

Sibir Appoints Chief Executive Officer
Sibir Energy announce that Mr Stuard Detmer has been confirmed as the Chief Executive Officer of Sibir. His experience in a senior management role within the Company since 2003 will ensure effective management continuity for the Company.

Total readies Shtokman tenders
French giant Total said recently that the Shtokman development partners were poised to launch the first round of tenders for the massive Barents Sea gas development, adding that it was "too early" to give an estimate for final project costs.

Total's Shtokman planning manager Philippe Rondy said: "Once the first tender bids are in place we will be in a position to talk about capital expenditure estimates. I expect this will be by the end of this year."

He said the Shtokman partners see the credit crunch as an opportunity to make cost savings, pointing out that the cost of steel has dropped since front-end engineering and design (FEED) work got under way in December 2007.

Plans for first pipeline gas deliveries in 2013, with the first liquefied gas cargo scheduled for 2014 remain in place he said with "The main technical solutions decided".

"We are opting for an ice-resistant floating production unit, and are planning to produce from 20 wells via three subsea templates."

Aker Solutions bags Sakhalin-1 gig
Norway's Aker Solutions is primed to build the Arkutun-Dagi gravity base structure (GBS) for the Sakhalin-1 project in Russia after receiving a contract award from operator Exxon Neftegas. Aker Solutions estimates the value for services could total $600 million over the next three years.

Once completed, the GBS will lie off Sakhalin Island on the east coast of Russia and will be a part of the drilling and production facilities for the Arkutun-Dagi development, a future phase of Sakhalin-1.

Transneft sees steady Russian output
Russian oil pipeline monopoly Transneft expects the country's crude production to remain stable this year, despite the economic slowdown, and will receive the first tranche of a $10 billion Chinese loan by the end of May, company president Nikolai Tokarev recently anounced.

"Volumes will stay at practically the same level," Tokarev told Reuters. Transneft is well-placed to calculate Russian oil production due to the orders it receives from producers to fill its pipelines. Tokarev said output would increase by 2012, although perhaps at a slightly slower rate than envisaged last year.

Russia's Surgut almost triples profit
Russia's fourth-largest oil company Surgut said its net profit almost tripled in the first quarter from the fourth quarter of 2008. The company said today that its net profit to Russian Accounting Standards stood at 68.79 billion roubles ($2.07 billion), up from 23.79 billion in the previous three months.

The company did not give a reason for the profit increase. Many Russian oil companies say their profits have recovered following a loss-making fourth quarter after oil prices stabilized and the Russian government cut oil export duties.

D&F Group takes a new name and becomes Beerenberg
The D&F Group has recently changed its profile, and will from now on conduct its business under the brand name Beerenberg as a consequence of the new ownership structure in 2006 and acquisition of Bjørge Norcoat in 2007, with the ambition for big growth internationally in 2009.

The name has been chosen that best fits the associations of the our company and services. Mount Beerenberg on the arctic island of Jan Mayen is Norway's only active volcano, and it is also the most northern, active volcano in the world. It is truly an extreme environment, much like the surroundings that the company have to face, and counter the effects of, on a daily basis.

PetroChina to boost storage for Russian oil
PetroChina's largest Daqing oilfield will add eight large crude oil storage tanks by 2010 after having installed two such tanks for offloading Russian oil. The 10 tanks alone, with planned capacity of 150,000 cubic metres each, will boost Daqing's crude oil storage capacity by nearly 10 million barrels, as China is set to ship in more Russian oil following the recent oil-for-loan deals between the two countries.

China agreed this month to lend $10 billion to Russian oil pipeline monopoly Transneft and another $15 billion to state-run oil major Rosneft in exchange for supplies via pipeline shipment of 300 million tonnes of Russian oil over 20 years.

The planned pipeline that will be used to transport Russian oil ends at the Daqing oilfield. China currently gets most of its Russian oil supplies via rail.

Oil production at Daqing, China's top oilfield by output, has been on a decline after decades of extraction.

ATR Group expands operations in Baku
ATR Group is unveiling an expanded offering in the Caspian, with a growing staff base in Baku alongside further cash investment in equipment serving the region. Aberdeen, Scotland-headquartered ATR made a major push into Azerbaijan in 2008, when it acquired Bridon International and is again developing its business with a stand at the Caspian oil show in June.The firm's Baku operation is now being led by highly experienced operations manager Malcolm Fox, who arrives as country manager with nearly 20 years experience in the oil and gas industry.

ATR director Robert Skidmore said: "Our work in the Caspian is developing apace and the addition of Malcolm Fox to our team gives our clients in the region access to a leading expert in his field.

EAGE St Petersburg 2010
The European Association of Geoscientists and Engineers (EAGE), joint with the Eurasian Geophysical Society (EAGO), will hold the 4th International Geosciences Conference and Exhibition "Saint Petersburg 2010, New discoveries through integration of geosciences". The conference will take place April 5-8, 2010 at the International Business Center in Saint Petersburg. More then 500 geosciences specialists are expected to visit the conference. The extensive scientific programme, including simultaneous work of several disciplines, will include workshops and courses from leading scientists. The exhibition will allow the opportunity to become more acquainted with the latest exploration and production technologies. Join us in Russia!

More information about the event: http://www.eage.org/

Labels: Aker Solutions, ATR Caspian, EAGE St Petersburg 2010, Gazprom, Lukoil, Nabucco, Roxi Petroleum, Russian oil gas news, Sakhalin, Shtokman, Sibir Energy, Surgut, TNK BP, Transneft, Uvat

posted by The Rogtec Team @ 10:48  0 Comments