Daily Archives: January 19, 2012

The Anti-Jobs President

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Obama rejects the Keystone XL pipeline and blames Congress.

The central conflict of the Obama Presidency has been between the jobs and growth crisis he inherited and the President’s hell-for-leather pursuit of his larger social-policy ambitions. The tragedy is that the economic recovery has been so lackluster because the second impulse keeps winning.

Yesterday came proof positive with the White House’s repudiation of the Keystone XL pipeline, TransCanada‘s $7 billion shovel-ready project that would support tens of thousands of jobs if only it could get the requisite U.S. permits. Those jobs, apparently, can wait.

Unless the President objected, December’s payroll tax deal gave TransCanada the go-ahead in February to start building the pipeline, which would travel 1,661 miles from Alberta to interconnections in Oklahoma and then carry Canadian crude to U.S. refiners on the Gulf Coast.

The State Department, which presides over the Keystone XL review because it would cross the 49th parallel, claimed yesterday that the two-month Congressional deadline was too tight “for the President to determine whether the Keystone XL pipeline is in the national interest.” The White House also issued a statement denouncing Congress’s “rushed and arbitrary deadline,” which merely passed with overwhelming bipartisan support.

This is, to put it politely, a crock.

Keystone XL has been planned for years and only became a political issue after the well-to-do environmental lobby decided to make it a station of the green cross. TransCanada filed its application in 2008, and State determined in 2010 and then again last year that the project would have “no significant impacts” on the environment, following exhaustive studies. The Environmental Protection Agency chose to intervene anyway, and the political left began to issue ultimatums and demonstrate in front of the White House, so President Obama decided to defer a final decision until after the election.

The missed economic opportunity was spelled out Tuesday by Mr. Obama’s own Jobs Council, which released a report that endorsed an “all-in approach” on energy, including the “profound new opportunities in shale gas and unconventional oil.” The 27 members handpicked by the President recommended that he support “policies that facilitate the safe, thoughtful and timely development of pipeline, transmission and distribution projects,” and they warned that failing to do so “would stall the engine that could become a prime driver of U.S. jobs and growth in the decades ahead.”

Only last week the White House issued a “jobs” report praising domestic energy production, but that now looks like political cover for this anti-jobs policy choice.

State did give TransCanada permission to reapply using an alternate route, timetable indefinite. The construction workers, pipefitters, mechanics, welders and electricians who might otherwise be hired for the project—well, they must be thrilled with this consolation prize. Not to mention all the other Americans who might fill “spin-off” jobs on the pipeline’s supply chain like skilled manufacturers and equipment suppliers, or still others who might work in oil refining and distribution.

Environmentalists seem to think they can prevent the development of Canada’s oil-rich tar sands, and that their rallies against Keystone XL will keep that carbon in the ground. They can’t, and it won’t. America’s largest trading partner will simply build a pipeline to the Pacific coast from Alberta and sell its petroleum products to Asia instead, China in particular.

Such green delusions are sad, and Mr. Obama’s pandering is sadder, though everything the country stands to lose is saddest. If Mitt Romney and the other GOP candidates have any political wit, they’ll vindicate the Keystone’s “national interest” and make Mr. Obama explain why job creation is less important than the people who make a living working for the green anti-industrial complex.

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Norway: Ulstein Delivers Blue Fighter PSV

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Ulstein Verft delivered M/V Blue Fighter, the first of two medium-sized platform supply vessels (PSV) of the new PX121 design from ULSTEIN® to Blue Ship Invest, on 19 January 2012.

“The two vessels were ordered based on market trends showing a future increase in demand for this type of PSV. We have entered into an agreement with Remøy Shipping for the management of Blue Fighter and we are negotiating interesting contracts for the ship. In the first instance the vessel will enter the North Sea spot market,” says Gunvor Ulstein, CEO of Ulstein Group and Managing Director of Ulstein Shipping.

Ulstein Verft was contracted to build the two vessels for Blue Ship Invest, a shipping company in ULSTEIN, at the end of 2010, and the first vessel, yard number 291, is delivered to the agreed terms.

The second vessel is due to be delivered from Ulstein Verft in Q3 of 2012.

“The delivery of the first PX121 confirms Ulstein Verft’s ability to build prototype vessels. Experienced people, streamlined processes and a well-established project organisation make us a competitive and reliable shipbuilding partner for advanced offshore support vessels,” says Karsten Sævik, Managing Director of Ulstein Verft.

Efficiency and flexibility has been the focus in the development of the PX121 design. With optimised tank capacities and flexible and segregated tank arrangements, the multifunctional vessel is suitable for many types of supply contracts. The ship is optimised for certain types of operations and adapted to the requirements for longer and deeper boreholes and activities further from shore. In addition to tanks for oil, water and drilling fluids, the vessel has four stainless steel tanks for flammable liquids.

X-BOW® hull

The vessel is built with the X-BOW® hull line design, which is particularly well-suited for this type of vessel. The X-BOW offers efficiency over a wide draught range, which is important for PSVs as they frequently operate with varying loads. Moreover, the X-BOW has unique, advantageous qualities in terms of motion and propulsion efficiency in heavy seas. Both the hull and choice of propulsion system make the vessel particularly suited for North Sea and North Atlantic conditions. The vessel is equipped with a dynamic positioning system IMO Class II.

The ship has a length of 83.4 metres and a beam of 18 metres. It has a cargo deck of 875 square metres and a load capacity of 4200 tonnes (dwt). The ship meets the requirements of DNV’s Clean Design notation and is prepared for fire-fighting class Fi-Fi II. It has a maximum speed of circa 15 knots and modern accommodation for 24 persons.

Ulstein Power & Control has delivered a substantial amount of equipment to the vessel, including switchboards, the information and communication system ULSTEIN COM®, the navigation system ULSTEIN NAV and the integrated automation system ULSTEIN IAS®.

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Australia: Exmouth Plateau Brings Joy to Chevron

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Chevron Corp. today announced a natural gas discovery in the Exmouth Plateau area of the Carnarvon Basin, offshore Western Australia.

The Satyr-3 well encountered approximately 243 feet (74 meters) of net gas pay. The well is located 113 miles (182 kilometers) north of Exmouth in the WA-374-P permit area, and was drilled in 3,688 feet (1,124 meters) of water to a depth of 13,369 feet (4,075 meters).

George Kirkland, vice chairman, Chevron Corporation, said, “Satyr-3 represents our thirteenth offshore discovery in Australia since mid-2009. This recent discovery reinforces the quality and value of our Australian exploration lease holdings in the Carnarvon Basin.”

Melody Meyer, president, Chevron Asia Pacific Exploration and Production Company, said, “The Satyr-3 discovery adds to our Australian resource base, further supporting our long-term plans to position Chevron as one of the world’s leading LNG suppliers.”

Chevron’s Australian subsidiary is the operator of the WA-374-P permit area and holds a 50 percent interest, with Exxon Mobil and Shell each holding 25 percent.

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Polarcus Acquires 3D Seismic Data Offshore Ivory Coast

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Rialto Energy Limited reports that a block‐wide, full‐fold 3D seismic survey covering 891km2 has been completed over Block CI‐202 (Rialto 85% and Operator) with Dubai-based contractor Polarcus DMCC.

Processing and interpretation of the newly acquired data will commence shortly and will provide Rialto with a full suite of 3D data over the entirety of Block CI‐202.

This will allow Rialto to further refine existing interpretation and mapping of the exploration potential within Block CI‐202 through better definition and mapping of the multiple prospects and leads already identified. Further, this work will provide an even greater understanding of the 5 existing discoveries and  culminate in better definition of these existing resources.

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Block CI‐202, offshore Côte d’Ivoire comprises an area of 675km2 and contains four significant underappraised oil and gas discoveries; Gazelle, Hippo‐1, Bubale, and Addax, all located in water depths of 50 to 100 metres. These discoveries  are assessed to have mean contingent resources totalling 50 mmbbls of liquids and 396 Bcf of gas. Rialto is moving to develop and commercialise the Gazelle field later this year. In addition to the development opportunities which exist within  CI‐202, the Company has identified an exciting inventory of exploration prospects and leads which will be the subject of future drilling.

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Technip USA Orders Deepwater Mooring Ropes for Lucius Spar

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Technip USA, Inc. has contracted Lankhorst Ropes to manufacture the polyester mooring ropes for a new spar platform for the US Gulf of Mexico.

The Lucius truss spar hull will be installed in a water depth of 2,165 metres (7,100 feet). The 23,000 ton spar is designed to produce 80,000 bopd of oil and 450 MMcfm/d of gas. First oil from the project is scheduled for 2014.

Lankhorst Ropes’ offshore rope production facility in Portugal will supply a total of 31,400 meters of their GAMA 98® polyester deepwater mooring rope with 1907tf (4200 kips) minimum breaking load. Production starts in January 2012.

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Chris Johnson, sales director, Lankhorst Ropes Offshore Division, said, “We are delighted to be working with Technip again. The Lucius contract is testimony to Lankhorst’s well proven, high quality GAMA 98® product which is already installed on three Gulf of Mexico floating production facilities since 2008”.

This will be the 15th spar platform to be delivered by Technip out of 18 worldwide. Detailed design and fabrication of the new hull will be carried out by Technip’s Pori yard in Finland, where most of the previous Technip Spar projects have been manufactured. Project management for will be carried out by Technip in Houston.

Anadarko operates the Lucius field (35%), and its partners are Plains E&P (23.3%), ExxonMobil (15%), Apache (11.7%), Petrobras (9.6%) and Eni (5.4%).

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Recap: Worldwide Field Development News Jan 13 – Jan 19, 2012

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This week the SubseaIQ team added 16 new projects and updated 32 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.

Africa – Other
Anadarko Successfully Appraises Lagosta Offshore Mozambique
Jan 17, 2012 – Anadarko Petroleum says its seventh well in the discovery area offshore Mozambique successfully appraised previous discoveries at Lagosta and Camarao. The Lagosta-2 appraisal well, located about 4.4 miles (7 kilometers) north of the Lagosta discovery and 5.3 miles (8.5 kilometers) south of the Camaro well, encountered 777 total net feet (237 meters) of natural gas pay in multiple zones. Anadarko says these results continue to support their recoverable resource estimates of 15 to 30-plus Tcf of natural gas in the discovery area, as well as provide additional information that will be incorporated into their models to help determine the optimal subsea development plans for the complex. The operator hopes to reach a final investment decision for this project in 2013. The Lagosta-2 appraisal well reached a total depth of about 14,223 feet (4,335 meters) in water depths of about 4,813 feet (1,467 meters) in the Offshore Area 1 of the Rovuma Basin. The partnership says it plans to preserve the Lagosta-2 well for future utilization during its planned drillstem testing program in the Windjammer, Barquentine and Lagosta complex. Once operations are complete, the Belford Dolphin (UDW drillship) will mobilize to drill the Lagosta-3 appraisal well.
Project Details: Lagosta
N. America – US GOM
McMoRan Begins Drilling in Blackbeard West
Jan 18, 2012 – McMoRan commenced exploratory drilling on the Blackbeard West No. 2 well on Nov. 25, 2011. The well is drilling below 11,700 feet (3,566 meters) with a proposed total depth of 26,000 feet. McMoRan is targeting Miocene-aged sands.
McMoRan to Flow Test Davy Jones No. 1
Jan 18, 2012 – McMoRan says completion activities of the Davy Jones No. 1 discovery well are at an advanced stage with flow testing expected in 1Q12. Initial production is expected shortly after a successful flow test. Furthermore, completion and flow testing of the Davy Jones No. 2 well are expected in the second half of 2012. Davy Jones is located on South Marsh Island Block 234 in 20 feet (6 meters) of water.
Project Details: Davy Jones
McMoRan Drills Deeper in Lafitte
Jan 18, 2012 – McMoRan says exploration results in the Lafitte well have indicated 211 net feet (64 meters) of possible productive sands, including 56 net feet (17 meters) in the Cris-R section of the Lower Miocene and 40 net feet (12 meters) in the Frio section. The well will be drilled below 32,400 feet (9,876 feet) to a proposed total depth of 33,000 feet (1,006 meters) to evaluate Oligocene and potential Eocene objectives. Lafitte is located on Eugene Island Block 223 in 140 feet (43 meters) of water.
Project Details: Lafitte
Africa – West
Rialto Energy Acquires 3D Data over Block CI-202
Jan 19, 2012 – Rialto Energy has completed a block-wide, full-fold 3D seismic survey covering 220,171 acres (891 square kilometers) over Block CI-202. Processing and interpretation of the newly acquired data will commence shortly and will provide the operator with a full suite of 3D data over the entire block. Rialto said that this will further refine existing interpretation and mapping of the exploration potential within the block through better definition and mapping of the multiple prospects and leads already identified. This data should provide a clear picture of the five existing discoveries and culminate in better definition of these existing resources. Rialto currently operates the CI‐202 block offshore Cote d’Ivoire, which contains the Gazelle Field. The field is the current focus of development with first production slated for 2012.
Project Details: Gazelle
Sonangol, TGS Reach Agreement for 3D Data Offshore Angola
Jan 18, 2012 – Sonangol and TGS have reached a final agreement for the acquisition of a 3D multi-client survey covering nearly 3 million acres (12,500 square kilometers) offshore Angola. The survey will initially commence over Blocks 36 and 37 in late January then continue over Block 35 with acquisition scheduled for completion in 3Q12. The high-potential pre-salt hydrocarbon play off the coast of Angola lies between 6,562 and 16,404 feet (2,000 and 5,000 meters) below sea level. TGS will process the 3D seismic data with final processed product expected by 4Q13.
Kosmos Strikes Again in Deepwater Tano Block Offshore Ghana
Jan 18, 2012 – Kosmos Energy has successfully appraised the Ntomme-2A well in the Deepwater Tano Block offshore Ghana, encountering significant quantities of light oil. The well was designed to test the potential of an oil leg beneath the previously-identified gas-condensate at Ntomme. Results of drilling, wireline logs and fluid samples indicate that the well encountered 148 feet (45 meters) of high-quality stacked reservoir sandstones, including 128 feet (39 meters) of 35 degree API gravity net oil pay. Pressure data from the well and the original discovery well suggests the potential of an oil column at Ntomme at about 410 feet (125 meters) below the gas-condensate accumulation. Ntomme-2A was drilled to an interim depth of 12,812 feet (3,905 meters) in a water depth of 5,675 feet (1,730 meters). Once drilling operations are completed, a drill stem test will be performed.
Project Details: Ntomme
Afren Makes Oil Discovery in Okoro East
Jan 17, 2012 – Afren has made a significant oil discovery in the Okoro East exploratory well offshore southeast Nigeria. The well encountered 549 feet (167 meters) true vertical thickness of net oil pay and 41 feet (12 meters) of net gas pay in excellent quality reservoir sands. The Okoro East exploration well was spud on Dec. 18 2011 and reached a total measured depth of 8,751 feet (2,667 meters) with the jackup Transocean Adriatic IX (350′ ILC). Afren says the well found oil in the Tertiary reservoir sands equivalent to those that have been developed and are in production at the Okoro main field, in addition to the deeper previously unexplored reservoirs. The discovery of significant pay in the previously unexplored deeper zones opens up further prospectivity at similar levels in the main Okoro field and elsewhere in the block, says the operator. Logging operations were completed and the well is now being prepared for testing, after which Afren will determine the optimal development of the discovery.
Asia – South
TNK-BP Commences Drilling Offshore Vietnam
Jan 19, 2012 – TNK-BP has commenced offshore drilling operations on the Lan Do field development project offshore Vietnam. The operator spud the Lan Do-2P well using the Ocean Monarch (UDW semisub). The Lan Do field contains two vertical subsea wells at a water depth of about 607 feet (185 meters). The sub-sea wells will connect to the Lan Tay Platform using a single 12-inch-diameter flow line. Gas production from Lan Do, which is scheduled to come on stream in the fourth quarter of this year, is expected to bring 2 Bcm of gas annually to sustain Block 06.1’s current production of 4.7 Bcm. TNK-BP acquired a 35 percent stake from BP and has become the operator of Block 06.1.
Asia – SouthEast
Lundin Touts Appraisal Results Offshore Malaysia
Jan 19, 2012 – Lundin Petroleum has appraised the Bertam-2 well in Production Sharing Contract PM307 offshore Peninsular Malaysia. Bertam-2 reached a total depth of 6,181 feet (1,884 meters) by the Offshore Courageous (350′ ILC) jackup. The objectives of the well were to appraise and test the Oligocene lower coastal plain sandstones of the PM307 PSC area. Discovered in 1995, the Bertam-1 well found oil in the K10 sandstone reservoir and flowed 34 degree API oil at a rate of 624 bopd on a short-term production test. The Bertam-2 well proved the continuity and quality of the K10 oil reservoir sandstone to the northeast of the Bertam-1 discovery well. Deeper sands that formed a secondary exploration target were confirmed to be water-bearing. The K10 reservoir sand was fully cored and logged. Preliminary interpretation indicates an oil interval with exceedingly large reservoir properties. During production testing, a stabilized flow rate of 756 bopd was achieved. Following testing, the well was plugged and abandoned and the rig demobilized. Bertam-2 is located to the northeast of the discovery well in 249 feet (76 meters) of water.
Project Details: Bertam
Rolls-Royce to Supply Gas Turbine, Compressor Equipment for Tapis Project
Jan 18, 2012 – Rolls-Royce has won an order for gas turbine and compression equipment for the Tapis oil and gas field, offshore Malaysia. The equipment will be utilized by ExxonMobil Exploration and Production Malaysia to expand and extend the production of the field. The order includes two Rolls-Royce RB211-GT61 gas turbines, each driving twin Rolls-Royce RCB and RBB multi-stage barrel gas compressors. Each gas turbine compressor set will produce 27MW of power, enough to deliver up to 390 MMcf/d of natural gas. The equipment is scheduled for delivery in 3Q12. The Rolls-Royce equipment will be installed at the Tapis enhanced oil recovery project featuring a central processing platform with a new integrated deck.
Australia
Chevron Hits Additional Gas Pay in Satyr-3 Well
Jan 19, 2012 – Chevron has successfully appraised the Satyr-3 well in the Exmouth Plateau area of the Carnarvon Basin, offshore Western Australia. The Satyr-3 well encountered about 243 feet (74 meters) of net gas pay. Satyr-3 reached a depth of 13,369 feet (4,075 meters) in a water depth of 3,688 feet (1,124 meters) by the Atwood Eagle (DW semisub). The well is located 113 miles (182 kilometers) north of Exmouth in the WA-374-P permit area.
Project Details: Greater Gorgon
Saipem Scores Gas Pipeline Gig for Ichthys Development
Jan 18, 2012 – Saipem signed an EPCI contract with INPEX for the gas export pipeline on the Ichthys LNG project offshore Australia. Saipem’s scope of work will include the engineering, procurement, construction and installation of 889 kilometers of a 42-inch-diameter subsea pipeline, in water depths of up to 902 feet (275 meters). The pipeline will connect the offshore complex to the onshore processing facility in Darwin. Offshore activities will be carried out during 2014 by the newly-built Castorone pipelay vessel. Gas from the field will undergo preliminary processing offshore to remove water and extract condensate. The Ichthys development is located on Block WA-285-P approximately 124 miles (200 kilometers) offshore Western Australia.
Project Details: Ichthys
Subsea 7 to Supply SURF Equipment for Fletcher, Finucane Development
Jan 17, 2012 – Santos granted Subsea 7 a US $60 million SURF contract for the Fletcher-Finucane development offshore Western Australia. The contract involves project management, engineering and installation of about 34 miles (55 kilometers) of flexible flowlines, more than 37 miles (60 kilometers) of umbilicals and associated structures to connect the wells to the existing Mutineer Exeter facilities. The contract also includes pre-commissioning activities and other associated services. Project management and engineering will begin immediately with offshore operations scheduled to commence late 2012.
Project Details: Fletcher/Finucane
Santos Sanctions Fletcher Finucane Oil Development
Jan 13, 2012 – Santos has sanctioned the $490 million Fletcher Finucane oil project in the Carnarvon Basin, offshore Western Australia. The project will be developed through a three-well subsea tie-back to the existing FPSO at Mutineer Exeter. First oil is slated for the second half of 2013 at an estimated average production of 15,000 bopd for the first 12 months.
Project Details: Fletcher/Finucane
Inpex, Total Give Nod to Ichthys Development
Jan 13, 2012 – Inpex and Total have greenlighted the Ichthys gas-export development offshore Australia. The $32.5B development is estimated to hold 12.8 Tcf of natural gas. Development plans for Ichthys include several subsea wells tied-back to a central floating offshore processing facility for gas, and an FPSO for condensate. Also, a 528-mile (850-kilometer) subsea pipeline will be constructed to transport the gas to a LNG processing plant in Blaydin Point, Darwin. The project is expected to produce 8.8 million tons (8 million metric tons) of LNG a year, with its first shipment being delivered in 2016.
Project Details: Ichthys
Mediterranean
San Leon Acquires Additional Seismic Data Offshore Albania
Jan 17, 2012 – San Leon Energy has received the first final processed volumes from its 207,569 acre (840-square kilometer) 3D seismic survey on its 100 percent-owned Durresi license in Albania. The survey was processed by Western Geophysical in London with a focus on detailed structural imaging, and incorporating relative amplitude preservation for the detection of subtle stratigraphic prospects on the flanks of the complex. The operator is currently processing the new 3D, as well as existing 2D seismic for the detection of stratigraphic traps. Initial results from the data have identified several large oil and gas prospects across the many petroleum systems that exist across the Durresi License, said the company. Plans to drill the first of a two-well exploration program on the block are being made for late 2012/2013.
Drilling Recommences at Leviathan-1
Jan 16, 2012 – Noble Energy has recommenced drilling at the Leviathan prospect. The Homer Ferrington (DW semisub) has arrived on location in the Rachel license drilling site and is expected to drill into the deeper targets of the well in the coming days. Drilling will continue where it left off in April 2011 for technical and operational reasons as reported in the past. Drilling is expected to last for three months. The Leviathan prospect is located in 5,361 feet (1,634 meters) of water at the Rachel and Amit license offshore Israel.
Project Details: Leviathan
S. America – Brazil
OGX Hits it Big at Fortaleza Prospect
Jan 16, 2012 – OGX has identified the presence of hydrocarbons in the Albian and Aptian sections of well 1-OGX-63-SPS in the BM-S-57 block, in the shallow waters of the Santos Basin. A hydrocarbon column of about 1,000 meters (3,280 feet) was encountered in Albian reservoirs with about 110 meters (360 feet) of net pay. The operator is still drilling the well but has already reached the Aptian section of the reservoir identifying hydrocarbons through a high-gas presence that resulted in a kick. OGX says this is under control. OGX-63 well, known as Fortaleza, is situated about 63 miles (102 kilometers) off Rio de Janeiro in a water depth of 509 feet (155 meters). The Ocean Quest (mid-water semisub) is drilling the well.
Project Details: Fortaleza
Europe – North Sea
Lundin Submits PDO for Luno Field
Jan 19, 2012 – Lundin Petroleum has submitted a plan for development and operation for the Luno field to the Norwegian Ministry of Petroleum and Energy. Lundin is in ongoing negotiations with Det norske, operator of license PL001B, in relation to a coordinated development solution for the Luno and nearby Draupne fields. The consortium expects an agreement to conclude shortly. The Luno development will incorporate both the Luno and Tellus discoveries, with first production expected in late 2015 with a forecast gross peak production of about 90,000 bopd. The capital cost of the Luno development including platform, pipelines and production wells are estimated at $4 billion. The Luno platform design capacity will accommodate in excess of 120,000 bopd when Draupne production is combined with the Luno field. The Luno PDO includes 15 wells drilled from a jackup rig, a processing platform on a jacket structure and export pipelines tied-back to existing infrastructure. Luno contains 186 MMboe of gross proved and probable reserves. The oil will be processed and transported in a new pipeline to the Grane area and further via the Grane oil pipeline to the Sture terminal. Lundin Petroleum has started placing contracts for the Luno development. A letter of intent has been awarded to Kvaerner, covering engineering, procurement and construction of the jacket for the Luno platform. A contract has been awarded to Rowan Companies for a jackup to drill the Luno development wells. Contracts for the topside and marine installations will be awarded soon. The Luno field is situated in PL 338 on Block 16/1 in the Norwegian sector of the North Sea in 354 feet (108 meters) of water.
Project Details: Luno
NPD Grants Det norske a Drilling Permit for Wildcat well
Jan 18, 2012 – The Norwegian Petroleum Directorate has granted Det norske a drilling permit for well 7/12-13S. Well 7/12-13 S will be drilled by the Maersk Guardian (350??? ILC) jackup in Production License 450. The area in the production license is located in the southern section of the North Sea, and comprises the southwestern part of block 2/4. The well will be drilled about six miles (nine kilometers) south of the Ula field. Det norske operates the license with a 75 percent interest; while Dana Petroleum holds the remaining stake.
Statoil Green Lights Dagny, Eirin Development
Jan 17, 2012 – Statoil and partners have selected a fixed platform development concept for the Dagny oil and gas discovery in the Norwegian sector of the North Sea, while the Eirin gas field is to be developed with a subsea solution. Gas from Dagny will be exported through a tie-back to the infrastructure on Sleipner East, while offshore loading into shuttle tankers is proposed for the oil. The seabed production installation on Eirin will be tied-back to the planned Dagny platform. Statoil says the chosen solution for Dagny and Eirin will now be secured, with the award of FEED contracts awarded shortly. Plans call for an investment decision to be taken next year, with production starting in 2016. Dagny is estimated to hold between 20 and 40 million Sm3 of recoverable oil equivalents. The Dagny oil field is located on Blocks 15/5 and 15/6 in the Norwegian North Sea in waters measuring 390 feet (119 meters).
Project Details: Dagny
Statoil Green Lights Dagny, Eirin Development
Jan 17, 2012 – Statoil and partners have selected a fixed platform development concept for the Dagny oil and gas discovery in the Norwegian sector of the North Sea, while the Eirin gas field is to be developed with a subsea solution. Gas from Dagny will be exported through a tie-back to the infrastructure on Sleipner East, while offshore loading into shuttle tankers is proposed for the oil. The seabed production installation on Eirin will be tied-back to the planned Dagny platform. Statoil says the chosen solution for Dagny and Eirin will now be secured, with the award of FEED contracts to occur shortly. Plans call for an investment decision to be taken next year, with production starting in 2016. Dagny is estimated to hold between 20 and 40 million Sm3 of recoverable oil equivalents. The Dagny oil field is located on Blocks 15/5 and 15/6 in the Norwegian North Sea in waters measuring 390 feet (119 meters).
Project Details: Dagny
RWE Dea Spuds Zidane-2 in North Sea
Jan 17, 2012 – RWE Dea has commenced exploratory drilling on the Zidane-2 well at Production License 435 in the Norwegian sector of the North Sea. The target of this well is to explore more gas reserves in the license. The West Alpha (mid-water semisub) is drilling the well to a vertical depth of about 15,748 feet (4,800 meters) in a water depth of 1,309 feet (399 meters). Drilling operations are expected to last 81 days with the possibility of an extension pending discovery.
Project Details: Zidane
Lundin Likely to Reduce Current Resource Estimates for Avaldsnes
Jan 16, 2012 – Lundin Petroleum has completed the 16/5-2S Avaldsnes appraisal well, located about 5.2 miles (8.5 kilometers) south of the discovery well 16/2-6 and two miles (four kilometers) south of the appraisal well 16/2-7. The objective of well 16/5-2S was to delineate the southern flank of the Avaldsnes discovery. Well 16/5-2S encountered a 49-foot (15-meter) Jurassic sequence of which the upper 26 feet (8 meters) has excellent reservoir quality. The top of the reservoir is deeper than expected, and below the oil water contact. Good hydrocarbon shows were observed below the oil water contact but were evaluated as not producable hydrocarbons. A comprehensive data acquisition program was performed, which including coring, wireline logging and fluid sampling. Results from the well will be incorporated into the current reservoir model, and a revised resource estimate will be released after the completion of the next appraisal well, 16/2-11. Well 16/5-2S is the first of an extensive Avaldsnes appraisal program compromising at least four wells in PL 501 during 2012. Lundin says this campaign will address key development planning uncertainties to ensure an efficient and optimal field development process for this discovery. The well was drilled to a total depth of 6,699 feet (2,042 meters) in a water depth of 364 feet (111 meters).
Project Details: Avaldsnes
Premier Oil Begins Drilling at East Fyne
Jan 16, 2012 – Premier Oil has started drilling operations on the East Fyne appraisal well in the UK sector of the North Sea Block 21/28a. Well 21/28a, located in the eastern portion of the Fyne field, is an Eocene Tay oil accumulation located southwest of, and on trend with, the producing NW Guillemot oil field.
Project Details: Fyne
Technip Wins Statoil Subsea Work
Jan 13, 2012 – Technip received two contracts for the Vilje South and Visund North developments in the North Sea in water depths of 394 and 1,263 feet (120 and 385 meters). These contracts cover welding and installation of a 6-mile-long (10-kilometer-long) production flowline; subsea equipment installation and tie-ins; and umbilical installation and tie-ins. Installation will occur in mid-2013.
Project Details: Alvheim
Statoil Shuts Snohvit Gas Field
Jan 13, 2012 – Statoil has shut production at the Snohvit gas field in the Barents Sea and LNG production at its Melkoya plant due to a ruptured fire water line. The rupture at the plant occurred Wednesday, January 13. The operator is working to eradicate the problem. Gas from the Snohvit field is transported to Melkoya for liquefaction and exports. Snohvit is located approximately 87 miles (140 kilometers) northwest of Hammerfest, Norway.
Project Details: Snohvit

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USA: TCEQ Says Grants Available for Gas Fueling Station

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The Texas Commission on Environmental Quality announced that up to $4.5 million in grants is being made available to eligible individuals, businesses, and governmental entities to support the development of a network of natural gas vehicle fueling stations to serve as a foundation for a self-sustaining market for natural gas vehicles in Texas.

The TCEQ Clean Transportation Triangle grants are part of the Texas Emissions Reduction Plan, and are offered to eligible entities that intend to build natural gas fueling stations along the interstate highways connecting Houston, San Antonio, Dallas, and Fort Worth.  These fueling stations must be located no more than three miles from the interstate highways and must be made available to the public.

CTT program goals include ensuring that natural gas vehicles purchased, leased or otherwise commercially financed, or re-powered under the Texas Natural Gas Vehicle Grant Program have access to fuel; and building the foundation for a self-sustaining market for natural gas vehicles in Texas.

Grants are offered to eligible applicants, with preference to be given to stations providing both liquefied natural gas and compressed natural gas at a single location; and stations located not more than one mile for an interstate highway system.

Application deadline is April 16, 2012.

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Polarcus Samur En Route to West Africa

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Polarcus Limited, a pure play marine geophysical company with a pioneering environmental agenda, specializing in high-end towed streamer data acquisition from Pole to Pole announces, has signed a Letter of Intent with an undisclosed client for a 3D seismic acquisition project offshore West Africa.

The project, to be acquired by POLARCUS SAMUR, will commence in late January and is expected to run for approximately 40 days.

Delivered Q1 2011 Polarcus Samur is an ultra-modern and Arctic-ready 8 streamer 3D vessel capable of towing both conventional and wide tow spreads, including Polarcus’ First Pass™ 3D technique requiring lateral streamer separations of 200m. Built to the ULSTEIN SX133 design and incorporating the innovative ULSTEIN X-BOW® hull, this vessel combines the latest developments in maritime systems with the most advanced seismic and source technol-ogy commercially available. The vessel is also amongst the most environmentally sound seismic vessels in the market with diesel-electric propulsion, high specification catalytic convertors, a double hull and advanced ballast water treatment / bilge water cleaning systems. The vessel complies with the stringent DNV CLEAN DESIGN notation.

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