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Update: Floatel Superior Stable Again. Will be Towed to Land, Statoil Says

After the PSA Norway today informed of Floatel Superior stability incident which occurred this morning in the Norwegian Sea, Statoil has provided a more detailed insight into the matter.

The oil company announced on its website that, after a hole was discovered in the rig’s ballast tank, causing the rig to tilt 3-4 degrees, the crew of 374 have mustered at the lifeboat stations and evacuation by helicopter is taking place.

“The rig’s stability is now re-established” Statoil said and added that Floatel Superior would be towed to land in due course.

Statoil has set up a personnel reception centre in Kristiansund. Six helicopters and an emergency response vessel have been deployed in order to assist the rig. In addition, an anchor handling vessel will be dispatched to inspect the damage.

Owned by the Swedish company Floatel, the Floatel Superior is a dynamically-positioned (DP-3) semi-submersible facility with a living quarters module aft and an open work deck forward.  The flotel can accommodate 440 people in single cabins when operating on the Norwegian shelf.

The PSA Norway in July 2012 granted consent to Statoil to use the  flotel at Njord Field in the Norwegian Sea.

Update: Floatel Superior Stable Again. Will be Towed to Land, Statoil Says| Offshore Energy Today.

Remote-controlled world record at Åsgard

For the very first time, remote-controlled machines and an underwater welding robot have installed a new tie-in point on a live gas pipeline, without the pipeline being prepared in advance.

Subsea Hot Tap Video Link

These types of operations can save Statoil lots of money in the long run.

The hot tap installation is the first to be carried out in connection with preparations for Åsgard subsea gas compression in the Norwegian Sea, and thus also represents a milestone for the project. The tie-in point was welded on to the Åsgard B production flowline at a water depth of 265 metres.

After ten days on the field, the hot-tap operation team on board the Technip-owned vessel Scandi Arctic could confirm success in the pioneering operation.

Kjell Edvard Apeland, project manager of the remote-controlled hot tap development in Statoil and head of the operation on the Åsgard field. (Photo: Rune Solheim)

“For a subsea engineer, this can be compared with landing on Mars,” says Kjell Edvard Apeland. He is project manager of the remote-controlled hot tap development in Statoil and head of the operation on the Åsgard field.

Simply explained, a remote-controlled hot tap operation consists of a robot welding a T-piece on to the pipe, while gas is flowing through it. When that has been done, a remote-controlled drilling machine will drill holes in the producing pipeline, with no effect on pressure and production.

“When the compressor module and the manifold for Åsgard subsea compression are installed next year, we will connect the pipeline from these to the hot-tap tie-in point,” says Apeland.

The Åsgard subsea compression project will be realised in 2015, as the first of its kind in the world. Compressors will be installed on the seabed, instead of on a platform. This will improve recovery from the Mikkel and Midgard reservoirs by around 280 million barrels of oil equivalents.

Major savings

Hot tap technology is a technological breakthrough, and a door opener for developing marginal fields, as well as extending the lifetime of other fields.

The ability to connect anywhere on a pipeline, without stopping production, yields considerable flexibility and significant savings.

Torstein Vinterstø, portfolio manager for subsea compression projects in Statoil. (Photo: Anette Westgård)

“Since we will be connecting a new compressor station on the seabed to an existing pipeline system on Åsgard, it is very beneficial to use the hot tap technology to avoid disrupting production,” says Torstein Vinterstø, portfolio manager for subsea compression projects in Statoil.

“The savings are measured compared with what it would have cost to perform a similar operation, including shutting down production in the pipeline we were working on. This would also have taken much longer than the ten days we spent now – possibly as long as three months,” he says.

Home-grown technology

The method was developed by Statoil, and there is no comparable technology.

The work to develop the technology started in 1999, and was developed in Statoil’s pipe technology environment at Killingøy outside Haugesund. Statoil’s expertise in tie-in and repair of pipelines is gathered there.

Open and constructive cooperation with our key suppliers has been instrumental in achieving this.

Statoil has already thoroughly tested the hot tap technology, with good results. Remote-controlled hot tap has previously been performed on Tampen Link on the Statfjord field in the North Sea and on the Ormen Lange field in the Norwegian Sea, but then the T-piece had already been installed on the gas pipeline in advance.

Source

Worldwide Field Development News Sep 8 – Sep 14, 2012

This week the SubseaIQ team added 3 new projects and updated 17 projects. You can see all the updates made over any time period via the Project Update History search. The latest offshore field develoment news and activities are listed below for your convenience.

Asia – SouthEast

Torquing the Bit for Gurame Appraisal

Sep 13, 2012 – The Gurame SE-1X well is expected to spud towards the end of September, according to MEO Australia. Success of the appraisal well could lead to early development of the Gurame oil and gas field situated offshore northern Sumatra in the Seruway PSC. The well was identified via 3D seismic as the lowest risk drill-ready candidate with the highest potential for commercial development. Drilling will be undertaken by the Hercules 208 (200′ MLC). Two attractive targets in the well, the Baong and Belumai reservoirs, are expected to be naturally fractured and gas bearing. These attributes should improve the possibility of achieving commercial flow rates. MOE maintains a 100% interest in Seruway.

Project Details: Gurame

Lundin Announces Third Gas Discovery

Sep 12, 2012 – The Berangan-1 well has proved to be Lundin Petroleum‘s third gas discovery in block SB303 offshore Malaysia. The well was drilled in 229 feet of water to a total depth of 5,607 feet by the West Courageous (350’ ILC). Data acquired from the well indicates a 541 foot gross continuous gas column in mid-Miocene sands. While Berangan-1 is the third gas discovery in SB303, it is the fourth in the contract area. Each of the 4 gas discovery lies within a 6 mile radius.

Project Details: Berangan

Phase II Approved for Galoc

Sep 11, 2012 – Otto Energy has approved the Final Investment Decision for Phase II of the Galoc field. Total project cost will be $188 million. Based on its working interest in the project, Otto will be funding 33 percent of the cost, or $62 million. The scope of work for Phase II includes drilling two subsea wells, tying back the wells to the existing FPSO and installing a second production riser and control umbilical. Both wells are expected to commence production during the second half of 2013. The two new Phase II wells will increase field production rates to 12,000 bopd from the current rate of 5,600 bopd.

Project Details: Galoc

Europe – North Sea

BP Sells Stake in Draugen

Sep 13, 2012 – BP has announced it reached an agreement to sell its 18.36% stake in Draugen Field in the Norwegian Sea to Norske Shell for $240 million. The deal, subject to regulatory approval, should be completed by the end of the year. BP’s net production from the Shell-operated Draugen field averages 6,000 barrels per day. Since 2010, BP has entered into agreements to sell assets valued at $33 billion. In an effort to focus more on growth opportunities and its core business strengths BP expects to divest $38 billion in assets between 2010 and 2013.

Project Details: Draugen

Providence Resources Confirms Plans for Dunquin Prospect

Sep 13, 2012 – Providence Resources has been informed by ExxonMobil that a letter of intent has been signed for the use of Ocean Rig’s Eirik Raude (UDW semisub). The rig will be used to drill the Dunquin prospect located in Frontier Exploration Licence 3/04 offshore Ireland. Program duration is expected to take up to 6 months and will commence in the first quarter of 2013, pending corporate and co-venture contract approvals. Partners in the exploration license include operator ExxonMobile (27.5%), Eni (27.5%), Repsol (25%), Providence Resources (16%) and Sosina Exploration (4%).

Project Details: Dunquin Project

Exploration Well Spuds at Geite

Sep 12, 2012 – JV partner Bridge Energy has announced the start of operations at exploration well 7/11-13 on the Norwegian continental shelf. The well is targeting the Triassic reservoir Geite prospect which is located 19 miles (30 kilometers) west of the Ula field. The Maersk Guardian (350′ ILC) is drilling the well and is expected to be on location for a minimum of 80 days.

Project Details: Geite

N. America – US Alaska

Shell Starts Drilling in Chukchi Sea

Sep 12, 2012 – Shell’s much anticipated Chukchi Sea drilling campaign is underway marking the first attempt in 20 years to explore offshore U.S. Arctic petroleum resources. Currently, the Noble Discoverer (mid-water drillship) is being used to drill the mud line cellar and top-hole sections of the first well. This is expected to take two weeks, after which the Discoverer will either continue drilling the Burger prospect or will move to another location to drill the top-hole section. Part of that decision will rest on whether or not the company is able to obtain a permit to drill past the surface sections into the oil bearing portion of the well. Shell has plans to drill three wells in the Chukchi Sea and two wells in the Beaufort Sea if the weather cooperates.

Project Details: Burger, SW Shoebill, Cracker Jack

Africa – Other

Apache’s Kenyan Well Hits Gas

Sep 11, 2012 – Africa-focused Tullow Oil reported Monday that the Mbawa-1 exploration well, currently being drilled by Apache Corporation offshore Kenya, has encountered gas in its shallowest objective. Mbawa-1, located in the L8 license, has so far been drilled to a depth of 8,375 feet and it has encountered approximately 170 feet of net gas pay in porous Cretaceous sandstones. The Deepsea Metro I (UDW Drillship) is now drilling the well to a total depth of 10,745 feet. Apache is the operator of Block L8 with a 50-percent interest. Tullow holds a 15-percent interest.

Project Details: Mbawa

Black Sea

Beach Gains 30% of Est Cobalcescu

Sep 12, 2012 – Melrose Resources has agreed to farm-out 30% of its equity in the Est Cobalcescu exploration concession in the Black Sea to Beach Petroleum. Once the transaction is completed, Melrose will retain operatorship of the concession. Terms dictate that Beach will pay its proportionate share of past costs and cover Melrose’s share of the recently completed seismic survey.

Africa – West

Partners Reprocessing Seismic Data for Aje

Sep 13, 2012 – The joint venture partners for Aje, led by YFP, are reprocessing seismic data related to the Aje discovery with a focus on the Cenomanian reservoir. The joint venture is mulling the potential for early oil development as the technical review could lead to an increase in Cenomanian oil volumes. An appraisal well may be drilled in 2013 targeting the reservoir.

Project Details: Aje

N. America – US GOM

Petrobras Turns on the Taps at Chinook

Sep 13, 2012 – Petrobras has started production at its Chinook field in the U.S. Gulf of Mexico. The Chinook #4 well was drilled and completed in Lower Tertiary reservoirs. Production from Chinook is processed by the BW Pioneer – the first FPSO to operate in U.S. waters.

Project Details: The Greater Chinook Area

Plains Buys Shell’s Stake in Holstein

Sep 12, 2012 – It has been announced that Plains Exploration & Production has agreed to buy Shell’s 50% working interest in the Holstein Field for approximately $560 million. The transaction is effective October 2012 and should close by the end of the year. Holstein, located in the U.S. Gulf of Mexico, began producing in December 2004 and is facilitated by a spar platform anchored in 4,400 feet of water. Average net production at the field is 7,400 boepd. The remaining 50% interest in the field is held by BP.

Project Details: Holstein

S. America – Brazil

Canario Spud Expected in Next Few Weeks

Sep 13, 2012 – Vanco is preparing to move the GSF Arctic I (mid-water semisub) to drill its Canario prospect on BM-S-63. This is the second well in their three-well program offshore Brazil. Drilling is expected to commence in approximately two weeks.

Project Details: Canario

Sabia Likely to Disappoint

Sep 13, 2012 – Vanco Energy’s Sabia well reached a depth of 13,779 feet when a decision was made to stop drilling short of the proposed depth of 14,717 feet. Based on current well data, the discovered volumes are at the low end of the pre-drill range estimate. While the well encountered an active petroleum system, the commerciality of the discovery cannot be firmly made at this time. The information obtained from the well is likely to have a positive impact on the next two prospects to be drilled – Canario and Jandaia.

Project Details: Sabia

First Production at Baleia Azul

Sep 12, 2012 – Petrobras has announced the start of oil production at the Baleia Azul presalt field in the offshore Camps Basin. First oil from the field is being pumped aboard the Cidade de Anchieta FPSO. The Cidade de Anchieta is one of two new production systems that Petrobras will put into operation in 2012. Initial production at Baleia Azul is a good sign for Petrobras whose oil production has taken a hit this year due to maintenance and unexpected shutdowns. The company has also announced plans to bring Bauna and Piracaba fields online in October. Petrobras holds a 100% stake in the fields.

Project Details: Espadarte

Shell Orders Subsea Connection Systems from Aker Solutions (Norway)

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Aker Solutions has been awarded a contract by A/S Norske Shell, to deliver subsea connection systems for the Draugen field on the Norwegian continental shelf. Contract value is approximately NOK 105 million.

Scope of work includes the delivery of complete tie-in connection systems for production flowlines and umbilicals for the expansion of the Draugen field.

“Aker Solutions has supplied connection systems for the subsea installations on the Draugen field since 2002. We are pleased that we can continue to assist A/S Norske Shell to expand the field and increase the production with our solutions,” says Alan Brunnen, executive vice president of Aker Solutions’ subsea business area.

Management, engineering and procurement of the connection systems will be performed at Aker Solutions’ head office in Fornebu, Norway. Equipment deliveries will be made from 2012 to 2013.

The Draugen field is located in block 6407/9 in the Haltenbanken area of the Norwegian Sea, which is situated about 140 kilometres from Kristiansund, Norway, at a sea depth of 250 metres.

Source

Norway: NPD Supports Statoil’s New Rig Concept for Subsea Wells

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The NPD encourages licensees in Statoil-operated production licences to support Statoil’s plans for using a new type of rig that is specially adapted for maintenance of subsea wells.

A letter sent to the relevant companies points out that recovery from producing fields is an important commitment area for the Norwegian Petroleum Directorate. An increasing percentage of the oil production on the Norwegian shelf comes from subsea wells, and the number of wells is increasing. The NPD has noted that it could be challenging to both drill new sidetracks from the subsea wells and carry out maintenance.

“That is why the Norwegian Petroleum Directorate is concerned with finding good solutions that can contribute to maintaining or increasing production from subsea wells,” says Torsten Bertelsen, director responsible for the Norwegian Sea and Barents Sea.

Statoil has long worked on a new type of rig for subsea wells, a so-called category B rig. It is permanently equipped for cables, coiled tubing and slim hole drilling and is specially adapted to well intervention campaigns. This type of rig can be used on multiple fields with subsea wells.

Use of such a rig will contribute to improve rig capacity, increase the number of subsea wells and thus improve recovery from subsea wells.

In the letter to the licensees the Norwegian Petroleum Directorate asks the companies to support Statoil’s project or to present alternative measures or projects that can yield similar effects.

“A cooperation on the new rig type across production licences is considered good resource management,” says Bertelsen.

Source

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