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Shell Plans USD 20 bln Investment in Indonesia’s Masela Block

International oil major Shell will invest approximately $20 billion in Masela offshore block, located the Arafura Sea, Indonesia.

According to Reuters, Indonesia’s Chief Economic Minister Hatta Rajasa said yesterday that Shell would gradually invest $20 billion between 2013 and 2019.

In December, 2011, Shell acquired a 30% participating interest in the Masela Block (Abadi project). Inpex is the operator of the project with 60% interest.

The Abadi gas field will be developed in phases and that one FLNG plant will be constructed and utilized for the annual LNG production of 2.5 million ton for the first phase development.

First production from the field is expected to begin in 2018.

Source

Dominion: Sierra Club Will Not Block Cove Point Liquefaction Project (USA)

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Dominion said yesterday it is confident that its existing agreement with the Sierra Club and the Maryland Conservation Council permits the company to build a natural gas liquefaction plant proposed for its Cove Point facility in Lusby, Md.

Thomas F. Farrell II, Dominion chairman, president and CEO, said:

“As with any project of this magnitude, we would expect some opposition from various special interest groups. The Sierra Club, which is a party to an agreement restricting activities on portions of the Cove Point property, has previously expressed its opposition to all LNG export facilities.  We have reviewed the regulations and agreements governing the site and are confident we can locate, construct and operate a liquefaction plant at Cove Point. The project can be built within the footprint of the existing facility without amending the agreement involving the Sierra Club and the Maryland Conservation Council. Dominion plans to design, build and operate the facility with minimal environmental impacts.”

Farrell said that by adding on to an existing facility, the Cove Point project would have less environmental impact than other liquefaction projects proposed for greenfield sites. He also noted that the Cove Point facility has been cited many times for its environmental stewardship, such as for the restoration of the 190-acre Cove Point freshwater marsh, a Maryland Natural Heritage Area along Chesapeake Bay.

Dominion announced earlier today it is moving forward with its natural gas liquefaction project at Cove Point. At the end of March, Dominion signed binding precedent agreements with two companies, one of which is Sumitomo Corp., a major Japanese corporation with significant global energy operations. Between the two shippers, the planned project capacity of about 750 million cubic feet per day on the inlet and about 4.5 million to 5 million metric tons per annum on the outlet, is fully subscribed. Construction is expected to begin in 2014, with an in-service date in 2017, pending receipt of necessary approvals, negotiating binding terminal service agreements with the shippers and successful completion of engineering studies.

Economic studies filed with Dominion’s federal approval applications anticipate a number of significant benefits from the project, including:

  • An average of 750 construction workers would be employed during three-plus years of construction. There will be between 2,700 and 3,400 jobs associated with the project in Calvert County alone at the peak of construction activity.  Benefits to the natural gas and other industries would support another 14,600 jobs once the shippers begin natural gas exports.
  • About $1 billion annually of additional federal, state and local government revenues would be generated directly and indirectly.
  • Owners of the natural gas rights would receive an estimated $9.8 billion in royalties from production of natural gas over the life of the project.
  • The natural gas exports would lower the U.S. trade deficit by $2.8 billion to $7.1 billion annually.

Source

Recap: Worldwide Field Development News (Feb 10 – Feb 16, 2012)

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This week the SubseaIQ team added 15 new projects and updated 33 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.

Australia
MEO Acquires Zeppelin 3D Data
Feb 13, 2012 – MEO Australia Limited has completed acquisition of the Zeppelin 3D seismic survey in AC/P 50 and AC/P 51 in the Ashmore Cartier region of the Timor Sea. A total of 125,530 acres (508 square kilometers) of full fold data was recorded. MEO said the Zeppelin 3D survey will underpin the technical assessment of the company’s exploration concepts and determine whether these will translate into prospects for consideration as future drilling candidates.
KBR to Commence FEED Work on Ichthys
Feb 10, 2012 – KBR and its joint venture with JGC Corporation and Chiyoda Corporation, the JKC JV, have signed a formal contract for engineering, procurement and construction activities on the Ichthys LNG Project in northern Australia. Work is slated to start immediately. Gas from the Ichthys field in the Browse Basin, approximately 124 miles (200 kilometers) offshore of Western Australia, will undergo preliminary processing offshore to remove water and extract condensate. The gas will then be exported to onshore processing facilities in Darwin via a 552-mile (889-kilometer) subsea pipeline. The Ichthys Project is expected to produce 8.4 million tonnes of LNG and 1.6 million tonnes of LPG per annum, along with approximately 100,000 barrels of condensate per day at peak.
Project Details: Ichthys
Europe – North Sea
Bridge Energy Develops Vulcan East, Looks to 2014 to Commence Production
Feb 16, 2012 – Bridge Energy reported that with Victoria Phase II development is scheduled to come online in 2013, the base case for delivery of the Vulcan East field will be in 2014. The Vulcan East gas field is located on Block 49/21 in the UK sector of the North Sea, and is wholly owned and operated by Bridge Energy.
DECC Approves Bridge Energy’s Victoria Phase 2
Feb 16, 2012 – Bridge Energy has received approval from United Kingdom Department of Energy and Climate Changes (DECC) for the development of the Victoria Phase 2 project in the fourth quarter. The company said preparations for the development of phase two continues, with the team focusing on the time critical technical and commercial agreements with ConocoPhillips for the transportation and processing of the gas. Bridge Energy has received an offer from ConocoPhillips for the transportation and processing of Victoria Phase II gas via the Viking facilities, LOGGS facilities and Theddlethorpe terminal. The offer provides for production startup in 2012. Bridge Energy says that the FEED stage of the Victoria Phase II development has commenced and the company is currently reviewing rig availability for 2012 and 2013. All other development activities are on schedule to meet a first gas date set in 1H 2013, subject to rig availability.
RWE Dea Spuds Clipper South Development Well
Feb 16, 2012 – RWE Dea has commenced development drilling at Clipper South in the UK sector of the North Sea. The development well, 48/19a-C1, is targeting a tight Permian-age Rotliegend reservoir at a depth of some 8,202 feet (2,500 meters) and is the first of up to five extended horizontal wells with multiple hydraulically induced fractures in each well. Clipper South contains roughly 500 Bcf of gas-in-place and will be developed using the latest well technology, stated the operator. First gas from the development is slated for this summer.
Project Details: Clipper South
Bridge Energy, TAQA Team Up for Contender Prospect
Feb 16, 2012 – Bridge Energy is planning to spud the Contender prospect in March 2012. The well will target the Jurassic Brent series of sandstones at a projected drilling depth of 16,900 feet (5,151 meters), less than one mile (two kilometers) east of the Cormorant North field. Drilling will be funded by TAQA. If successful, TAQA will receive 60 percent interest in the southern area of the block and 35 percent interest in the northern part. Contender is located in UKCS License P201 on Block 211/22a.
Project Details: Contender
Total to Drill Garantiana in 3Q12
Feb 16, 2012 – Total is planning a spud date in 3Q 2012 to drill the Garantiana prospect in the Norwegian sector of the North Sea. The prospect straddles Blocks 34/6 and 34/9 and lies in a water depth of 1,247 feet (380 meters).
Project Details: Garantiana
Aker to Deliver Subsea Equipment for Troll Field
Feb 16, 2012 – Statoil awarded Aker Solutions a contract to deliver six subsea trees and a tool package for Troll in the Norwegian sector of the North Sea. The scope of work includes six subsea trees, with a possible option for nine further subsea trees, including control systems. Under this contract, Aker Solutions will deliver equipment to the oil section of Troll. The Troll field, containing 40 percent of the total gas reserves on the Norwegian continental shelf, is the world’s biggest subsea development with regards to the number of subsea wells. Equipment deliveries are slated for 2012 until 2015.
Project Details: Troll Area
Det norske Gets Nod to Explore PL 460
Feb 15, 2012 – Det norske has received consent to carry out exploration drilling in the North Sea using the Transocean Barents (UDW semisub). The consent relates to the drilling of exploration well 25/1-12 in Production License 460. The water depth of the site is 335 feet (102 meters). Drilling is slated for 2Q 2012 and will take about 40 days.
Kvaerner Wins Jacket EPSC Gig at Hild Field
Feb 14, 2012 – Total has awarded Kvaerner an EPSC-contract for the delivery of a steel jacket to be located at the Hild field in the Norwegian sector of the North Sea. The contract includes engineering, procurement, supply, construction, load-out and sea-fastening of the jacket and associated piles. The jacket is slated for delivery in 2014.
Project Details: Hild
Hurricane Mulling Lancaster Development Plans
Feb 14, 2012 – Hurricane Resources believes that its Lancaster development, west of the Shetland Islands, contains 200 MMbbl of recoverable oil. This estimate is based on a thorough evaluation of the original Lancaster pilot well, drilled in 2009 and its subsequent sidetrack drilled in 2010. The company said that prior to the proposed 2012 drilling operations, Hurricane has commissioned a site survey and is now planning for future Lancaster appraisal and development wells. These wells are targeted at improving the company’s understanding of the structure’s upside and confirming delivery rates from a basement horizontal well. Hurricane is also working with EPC Offshore on several development scenarios for the discovery. The consortium is leaning towards a development plan including several subsea wells connecting to an FPSO with oil exported to the mainland by a shuttle tanker.
Project Details: Lancaster
Hurricane Targeting 2014 to Drill Lincoln Prospect
Feb 14, 2012 – Hurricane reported that a third basement prospect on License P1368, Lincoln, has been defined to the southwest of Lancaster, in the UK sector of the North Sea. The prospect shares many geological characteristics with Lancaster, including proven oil on structure and a well defined basement fault system. Technical work undertaken during the latter half of 2010 and the first half of 2011 resulted in a prospective well location being identified, and subsequently a site survey has been acquired. Prospective P50 recoverable resources are estimated at 150 MMbbl. Well planning for a Lincoln exploration well is ongoing with the objective of drilling in 2014.
Project Details: Lincoln
Hurricane Exploration Acquires Site Survey Over Typhoon
Feb 14, 2012 – Hurricane Exploration acquired a site survey over the Typhoon prospect during the summer of 2011 and is now working on well plans with the objective of drilling in 2012, subject to rig availability. Prospective resources could be in the range 149 MMbbl to 1.266 Bbbl.
Project Details: Typhoon
Providence Resources Confirms Plans for Dunquin Prospect
Feb 13, 2012 – Providence Resources has confirmed the forward program for Frontier Exploration License (FEL) 3/04, which contains the Dunquin exploration prospect. The consortium approved the 2012 budget, including the provision of well design activities and procurement of long-lead items as part of the ramp up to the drilling of an exploration well on the Dunquin prospect next year. Providence plans to spud the exploration well in the second quarter of 2013. The FEL 3/04 license covers five blocks in the South Porcupine Basin, 124 miles (200 kilometers) off the southwest coast of Ireland, where the water depth is more than 4,921 feet (1,500 meters).
Project Details: Dunquin Project
Det norske Comes Up Dry at Kalvklumpen Prospect
Feb 13, 2012 – Det norske announced that exploratory well 25/6-4 S on the Kalvklumpen prospect in Production License 414 has come up dry. The primary objective of the well was to prove hydrocarbons in Paleocene and Jurassic sandstone. Det norske said the well struck good quality reservoir rocks but the formation was water-bearing. The well will now be permanently plugged and abandoned.
Project Details: Kalvklumpen
Wintershall Receives Consent to Explore PL 418
Feb 10, 2012 – Wintershall Norge has received consent to carry out exploratory drilling in the Norwegian sector of the North Sea using the Songa Delta (mid-water semisub). The consent relates to the drilling of exploration well 35/9-7 which belongs to production license 418, at which Wintershall acts as operator. Water depth of the site is 1,237 feet (377 meters). Drilling operations should last about 48 to 60 days, depending on whether a discovery is made.
Lundin Gets Govt Nod to Drill Albert Prospect
Feb 10, 2012 – Lundin Norway has received consent to carry out exploratory drilling in the Norwegian sector of the North Sea with the Bredford Dolphin (mid-water semisub). The consent permits Lundin to act as operator at exploratory well 6201/11-3, which is part of production License 519. Water depth of the site is 1,257 feet (383 meters). Drilling operations should take roughly 53 days, depending on whether a discovery is made.
Project Details: Albert
Black Sea
Petrom Eyes Hydrocarbons in Romanian Black Sea
Feb 10, 2012 – Petrom announced that natural gas was encountered at Domino-1, the first deepwater exploration well in the Romanian sector of the Black Sea. The operator said it is too early in the data evaluation and exploration process to determine whether it is commercial or not. Drilling operations commenced at year-end 2011 and are ongoing. The total depth of the well should be more than 9,843 feet (3,000 meters) below sea level. Drilling operations are being carried out by the Deepwater Champion (DW drillship).
Project Details: Domino
Asia – South
DDE-A-2 Well Spud in Deen Dayal East
Feb 13, 2012 – Jubilant Energy announced that appraisal well DDE-A-2 was spud on 9 February 2012. DDE-A-2 is being drilled in a water depth of 325 feet by Aban Offshore’s Deep Driller-1 jack-up rig. This is the third appraisal well in the Deen Dayal East (“DDE”) area of the KG-OSN-2001/3 block. The target depth of the well is 17388′ TVD with the objective of appraising the lower Cretaceous Early Rift fill sands that were shown to be hydrocarbon bearing by the KG-16 discovery well. Gujarat State Petroleum Corporation Limited operates the KG block with an 80% interest. The remaining ownership is split between Jubilant Energy and GeoGlobal Resources.
Project Details: Deen Dayal
ONGC Hits Gas Offshore India
Feb 10, 2012 – ONGC has made a shallow water gas discovery offshore India. Exploratory well Alankari No. 1, in NELP Block KG-OSN-2004/1 in the KG shallow offshore Basin, was drilled to a depth of 6,273 feet (1,912 meters). The 6,002 to 6,010 foot (1,829.5 to 1,832 meter) interval in the Godavari clay/Ravva formation of Mio-Pliocene age was formation tested, producing gas at a rate of 144,780 MMcm/d and condensate at 1.6 cu M/d. The gas discovery is located south of Narsapur, Andhra Pradesh, 4.3 miles (7 kilometers) from the coast in a water depth of around 69 feet (21 meters).
ONGC Strikes Again Offshore India
Feb 10, 2012 – ONGC said exploratory well GSS04NAA No. 1 in NELP Block GS-OSN-2004/1 in Saurastra offshore, Western offshore basin, reached a depth of 16,033 feet (4,877 meters). The 15,733 to 15,697 foot (4,795.5 to 4,784.5 meter) interval of Mesozoic age was also formation tested, and produced gas at a rate of 1.4 MMcf/d through a 1/4-inch choke. ONGC claims this discovery provides a significant lead to explore other sub-basalt Mesozoics in the area. Exploratory well GSS04NAA No. 1 is located southwest of Dwarka, Gujarat, about 56 miles (90 kilometers) offshore in a water depth of around 328 feet (100 meters).
Mediterranean
Dolphin Gas Field Estimate Downsized by 85 Percent
Feb 13, 2012 – Netherland Sewell & Associates have cut the estimated size of the Dolphin natural gas reservoir by 85 percent to approximately 81.3 Bcf of gas from 550 Bcf of gas. The operator has yet to finalize field development plans.
Project Details: Dolphin
Africa – Other
Eni All Smiles Over Mamba North
Feb 15, 2012 – Eni has made a “massive” natural gas discovery at the Mamba North 1 prospect, in Area 4 offshore Mozambique, encountering a mineral potential of 7.5 Tcf of gas-in-place, reported the company. This new discovery, in addition to the Mamba South find made in October 2011, further increases the potential of the Mamba complex in Area 4. It is estimated that the total volume of gas-in-place is 30 Tcf. The well encountered 610 feet (186 meters) of gas-bearing rock. A production test was conducted, producing about 1 MMcm/d of natural gas and minor volumes of condensate during testing, but flow rates were constrained by surface facilities. Eni estimates output per well could reach more than 4 MMcm/d in a final production completion configuration.
Project Details: Mamba South/North
N. America – US GOM
Shell Successfully Appraises Appomattox
Feb 16, 2012 – Shell has successfully appraised the Appomattox discovery in Mississippi Canyon Block 348 in the GOM. The well, located in a water depth of 7,257 feet (2,212 meters), reached a total depth of 25,851 feet (7,879 meters) and encountered about 150 feet (46 meters) of oil pay. The operator will continue to appraise the find in 2012 with an additional well in the southwest fault block and a sidetrack appraisal in the northwest fault block to further delineate the hydrocarbon accumulation. Further Appomattox and Vicksburg appraisals, if warranted, may extend into early 2013, stated Shell.
Project Details: Appomattox
Correction to 2/2/12 Telemark Well Activities
Feb 15, 2012 – We previously reported on February 2, 2012, ATP’s completion of drilling operations at Mississippi Canyon 942 and erroneously referred to it as Thunder Horse instead of Telemark.
Project Details: Telemark
Africa – West
Hyperdynamics Completes Drilling of Sabu-1 Well Offshore Guinea-Conakry
Feb 14, 2012 – Hyperdynamics has completed drilling the Sabu-1 exploration well on its concession offshore Guinea-Conarky. The well reached a depth of 11,844 feet (3,610 meters) in a water depth of 2,329 feet (710 meters). Results of real-time hydrocarbon chromatograph measurements and Schlumberger petrophysical wireline analysis warranted collection of downhole fluid samples. These samples, together with sidewall cores taken, are being sent to Core Lab for analysis, reported the operator. Hyperdynamics will be incorporating the results of the well, along with the interpretation of the newly acquired 3D seismic, in order to plan the subsequent drilling program in consultation with Dana Petroleum and the government of Guinea.
Project Details: Sabu

 

SubseaIQ

Brazil: OGX Encounters Huge Hydrocarbon Column in Santos Basin

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OGX, a largest privately owned oil & gas company in Brazil, today announced that it 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. OGX holds a 100% working interest in this block.

“This discovery is important for its huge hydrocarbon column and net pay identified in the Albian section, as well as by the quality of the Aptian reservoir and its behavior,” commented Paulo Mendonça, General Executive Officer and Exploration Officer of OGX.

A hydrocarbon column of approximately 1,000 meters was encountered in Albian reservoirs with about 110 meters of net pay. The drilling of the well, which is still in progress, already reached the Aptian section of the reservoir identifying hydrocarbons through a high gas presence that resulted in a kick, which is already controlled.

The OGX-63 well, known as Fortaleza, is still in progress and located in the BM-S-57 block and is situated approximately 102 kilometers off the coast of the state of Rio de Janeiro at a water depth of approximately 155 meters. The Ocean Quest rig initiated drilling activities on October 08, 2011.

Articles

Source

Angola: Azul-1 Deepwater Well Brings Oil to Maersk Oil

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Songangol, Maersk Oil and other partners declared the Azul-1 deepwater exploration well, located in Block 23 in the Kwanza Basin offshore Angola, a discovery well.

The Azul-1 well, the first to penetrate pre-salt objectives in Angolan deepwater, was drilled in water depths of 923 meters and reached a final depth of 5,334 meters. The condition of the well prevented an assessment of flow capacity by a conventional test. This was performed as a mini-Drill Stem Test that enabled the recovery of two good quality oil samples.

The preliminary interpretation of the data indicated a potential flow capacity greater than 3,000 barrels of oil a day. Taking into account these encouraging results, Maersk Oil will further evaluate the results of this discovery and will proceed with exploration work in the block.

Sonangol E.P. is the block Concessionaire. Maersk Oil is operator of Block 23 with a 50% working interest with partners Svenska (30%) and Sonangol P & P (20%).

“We are encouraged by the results of our first pre-salt exploration well in this region, which was also the first ever deep water well targeting pre-salt reservoirs in the Kwanza Basin. The result may be a further step towards our goal of building up a significant business in Angola,” said Lars Nydahl Jorgensen, Head of Exploration at Maersk Oil.

“There is substantial evaluation work ahead of us to determine whether the discovery is enough to invest further to get production going. This will be done by, amongst other things, state of the art reprocessing of seismic data. Fully appraising the discovery will take several years and it is far too early to guess the outcome,” Jorgensen said.

Articles

Source

Worldwide: Project Field Development News

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Worldwide Field Development News
Dec 2 – Dec 8, 2011
This week the SubseaIQ team added 2 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.

Mediterranean
Northern Obtains Seismic Data from Adriatic Sea
Dec 7, 2011 – Northern Petroleum completed a 148,263-acre (600 square kilometer) 2D seismic survey offshore Southern Adriatic covering two licenses, F.R39.NP and F.R40.P. Seismic acquisition began last month using the vessel ‘M/V Princess’ contracted from CGGVeritas S.AA. Completion of the acquisition occurred within the prescribed six-day period. The work program, including this seismic acquisition, aims to obtain complete and better quality data to improve definition of the promising prospects identified from older seismic surveys. A further 3D seismic is planned in 2012 and will commence once approvals are obtained from all relevant authorities. The F.R39.Np and F.R40.P permits include the Rovesti and Giove oil discoveries and 10 mapped prospects. Northern and partner, Azimuth, intend to define and delineate suitable appraisal and exploration drilling targets.
Europe – North Sea
Det norske Gets Nod to Drill Wildcat Well 25/6-4 S
Dec 7, 2011 – The Norwegian Petroleum Directorate has granted Det norske a drilling permit for well 25/6-4 in the Norwegian sector of the North Sea. The Songa Delta (mid-water semisub) will drill the well in 114 meters of water. The drilling program for well 25/6-4 S applies to the drilling of a wildcat well in Production License 414. Det norske is the operator of the license with a 40 percent interest. Partners in the license include Faroe (20 percent), Bayerngas (20 percent) and Noreco (20 percent).
Centrica Successfully Appraises Butch Discovery
Dec 7, 2011 – Centrica announced that appraisal results at its Butch exploration well have indicated a significant presence of light oil in the reservoir. The operator said preliminary resource estimates specify a discovery of between 30 to 60 MMboe for the main Butch segment. Further data collection is now underway and the drilling of a second sidetrack well has commenced on the Butch southwest compartment, where the well is targeting additional volumes. The discovery lies in 217 feet (66 meters) of water and is close to existing infrastructure. Centrica Energi has a 40 percent operating interest in Butch discovery; while Suncor Energy holds 30 percent; Spring Energy holds 15 percent and Faroe Petroleum holds 15 percent.
Project Details: Butch
Total Acquires GDF Suez’s Stake in Elgin/Franklin
Dec 7, 2011 – Total has purchased GDF Suez’s share in the Elgin, Franklin fields (this participation is held through a 22.5 percent stake in the company, Elgin Franklin Oil & Gas). By giving Total control of the whole of the capital of EFOG, which it previously held 77.5 percent, this acquisition increases its share in the Elgin/Franklin fields from 35.8 percent to 46.2 percent. Following the completed transaction, the partners in Elgin/Franklin will be EFOG (Total 100 percent) 46.2 percent; Eni 21.87 percent; BG 14.1 percent; E.ON Ruhrgas 5.2 percent; Esso Exploration & Production 4.4 percent; Chevron 3.9 percent; Dyas 2.2 percent; and Summit Petroleum 2.2 percent. The Elgin/Franklin development produces approximately 140,000 boed. Located in the Central Graben area of the UK North Sea about 149 miles (240 kilometers) east of Aberdeen, the Elgin and Franklin fields are 4 miles (6 kilometers) away from each other in waters measuring 305 feet (93 meters).
Project Details: Elgin/Franklin
Antrim Hits Pay in Erne Well
Dec 7, 2011 – Antrim Energy has made a discovery in the Erne exploratory well, 21/29d-11, in the UK sector of the North Sea. The well reached a total depth of 5,562 feet (1,695 meters), encountering a gross hydrocarbon column in excess of 50 feet (15 meters) in the Eocene Upper Tay sandstone. This includes 20 feet (6 meters) of net oil pay and 10 feet (3 meters) of net gas pay, with average porosity exceeding 30 percent, and average hydrocarbon saturation of about 80 percent. The operator will now drill a sidetrack well from the pilot hole to further delineate the reservoir. Erne is located in Block 21/29d in the UK sector of the North Sea. Antrim Energy operates Block 21/29d.
Project Details: Erne
Statoil Gets Nod to Drill in Barents Sea
Dec 5, 2011 – The Norwegian Petroleum Directorate has granted Statoil a drilling permit for wellbore 7220/7-1 in the Barents Sea. The Aker Barents (UDW semisub) will drill the well. The drilling program applies to the drilling of a wildcat well in Production License 532. Drilling will occur about 62 miles (100 kilometers) northwest of the Snohvit field. Statoil serves as the operator of the permit with a 50 percent interest. The other licensees are Eni (30 percent) and Petoro (20 percent).
Statoil Reaches Investment Decision for Visund North
Dec 5, 2011 – Statoil and partners have reached an investment decision for the Visund North development in the North Sea. Recoverable reserves are expected to be 29 MMbbl of oil equivalents, consisting mainly of oil. The development entails a standard seabed template with two wells, to be manufactured by FMC, and installed in the summer of 2012. The oil will transport to Visund A through a new pipeline system, for processing on the platform. Statoil says that all of the main contracts have been awarded, apart from marine installations and platform modifications. These are planned to occur by the end of the year. Production is slated for 2013. The oil and gas field is located in Blocks 34/8 and 34/7, which Statoil operates.
Project Details: Greater Gullfaks Area
Providence Receives Exploration License 2/11
Dec 2, 2011 – Providence has acquired Standard Exploration License 2/11 in the Kish Bank Basin, offshore Dublin. The granted license has a time period of up to six years and is split into two three-year phases. The license is a successor authorization to the previous License Option 08/2. License 2/11 contains the Dalkey Island exploration prospect, which the partners have committed to drill during the first phase. The partners have recently commenced the application process for a foreshore license over the area in order to carry out well site survey and drilling operations. Providence operates the license with a 50 percent interest.
Project Details: Dalkey Island
N. America – US GOM
FMC Technologies to Deliver Subsea Equipment for Who Dat Field
Dec 8, 2011 – FMC Technologies has signed an agreement with LLOG Exploration Limited for the design, manufacture and supply of subsea production systems for the Who Dat development in the GOM. FMC’s scope of supply includes seven subsea production trees and control systems. Delivery of the equipment is slated for 2012. The Who Dat field, situated in 3,000 feet (914 meters) of water, is expected to commence production in 3Q11. LLOG operates the field with a 67.5 percent interest.
Project Details: Who Dat
S. America – Other & Carib.
FOGL to Spud Loligo in Late April/Early May
Dec 7, 2011 – FOGL announced that the Leiv Eiriksson (mid-water semisub) has left Greenland and is now en route to the Falkland Islands for the upcoming B&S and FOGL drilling program. The company plans to spud the Loligo prospect in late April or early May 2012, and the second well to spud on completion of Loligo. Loligo is a Tertiary Channel play structure with estimated Pmean reserves of 4.7 Bbbl. The Loligo complex comprises several reservoir objectives along with a number of various reservoir targets. The well is located in the Falkland Islands.
S. America – Brazil
ANP Orders Chevron to Shut-In Well at Frade Development
Dec 2, 2011 – The National Petroleum Agency has ordered Chevron Brasil Upstream to shut-in one production well and four water injection wells at the Frade FPSO offshore Brazil. ANP submitted this requested after conducting a safety audit of the vessel and found that sulfide gas has been leaking. The closed production well accounts for less than 10 percent of the field’s total production output of about 79,000 bopd, stated the operator. The field is situated in the Campos Basin in approximately 3,700 feet (1,128 meters) of water, roughly 230 miles (370 kilometers) northeast of Rio de Janeiro. Frade is a subsea development with wells tied-back to the Frade FPSO.
Project Details: Frade
Africa – West
Vanco Makes a Discovery in Independence-1X Well
Dec 7, 2011 – Vanco Cote d’Ivoire and partners have made a discovery in the Independence-1X exploratory well in Block CI-401. The discovery has penetrated the targeted objective and found a series of good-quality sandstones containing light oil. Full review of well results, including wireline logs, reservoir pressures and fluid samples, confirm that the well penetrated 8 meters (26 feet) of hydrocarbon pay in good-quality Turonian-aged sand package. Recovered hydrocarbon samples from Independence-1X well indicate the oil registers at 40 degree API gravity. The operator will temporarily abandon the well at a total depth of 13,556 feet (4,132 meters). The Ocean Rig Olympia (UDW drillship) drilled the well in a water depth of 5,541 feet (1,689 meters). Vanco (Operator) holds a 28.34 percent participating interest.
Asia – SouthEast
Lundin Spuds Bertam-2 Offshore Malaysia
Dec 8, 2011 – Lundin Petroleum has spud the Bertam-2 appraisal well in PM307 Production Sharing Contract area, offshore Peninsular Malaysia. The total depth of the well is 6,194 feet (1,888 meters) and is being drilled by the Offshore Courageous (400’ ILC) jackup. The objectives of the well are to appraise and test the Oligocene lower coastal plain sandstones of the PM307 PSC area, and to test the continuity and quality of the K10 oil reservoir. The operator will also explore the deeper sands in an independent closure on the northern side of the structure. Discovered in 1995, the Bertam well hit oil in the K10 sandstone reservoir. While conducting a flow test, the well produced 34 degree API oil at a rate of 624 bopd. Bertam-2 is located to the northeast of the discovery well in 249 feet (76 meters) of water. PM307 PSC is operated by Lundin Malaysia with a 75 percent interest; Petronas holds the remaining interest.
Australia
AWE Sells BassGas Stake to Toyota Tsusho
Dec 8, 2011 – AWE Limited will sell an 11.25 percent stake in T/L1, and a 2.75 percent interest in T/18P in the BassGas project to Toyota Tsusho for a cash consideration of A$80.125 million. The T/L1 permit includes the Yolla gas and condensate field and its associated production infrastructure, and a 2.75 percent interest in T/18P, which includes the Trefoil gas and condensate discovery. Once the agreement is finalized, AWE will hold a 46.25 percent interest in T/L1 and a 44.75 percent interest in T/18P.
Project Details: BassGas Project
Chevron, FMC Team Up for Subsea Equipment for Wheatstone
Dec 8, 2011 – Chevron granted FMC Technologies a contract for the design, manufacture and supply of subsea production systems to support the Wheatstone project. The scope of supply includes 11 subsea production trees, 11 wellheads, three manifolds, subsea and topside controls and well access systems. Delivery of the equipment is scheduled to commence in 2013. The Chevron-operated Wheatstone project, situated offshore Australia, compromises the Wheatstone and Iago gas fields, located in water depths between 330 and 850 feet (100 to 260 meters).
Project Details: Wheatstone
Eni Commences 3D Seismic over Blackwood
Dec 7, 2011 – Eni has commenced a Bathurst 3D seismic survey over the Blackwood East area of permit NT/P68. The field acquisition program is scheduled for completion within 50 days. Under the terms of the farm-in agreement, Eni will pay MEO’s share of the costs to acquire and process the 3D seismic survey. The company will have 365 days from completion of the acquisition to elect whether or not to exercise its option to drill, and pay 100 percent of the cost of the Blackwood-2 well in order to retain its 50 percent interest in the gas discovery. The CGG Veritas seismic vessel, M/V Veritas Viking II is acquiring the 172,480-acre (698-square kilometer) seismic survey.
Project Details: Blackwood
Eni Purchases Additional Interest in Evans Shoal Field
Dec 7, 2011 – Eni has purchased a 32.5 percent stake in the Evans Shoal gas field in the Timor Sea, Australia. The undeveloped field, discovered in 1998, holds expected gas-in-place of up to 7 Tcf. Subject to completion of the purchase of Santos-interests, in a separate transaction, Eni has agreed to sell a 7.5 percent equity share in exploration permit NT/P48 to Shell. Both transactions are subject to the regulatory authority. Following the approved transaction, the partners in the revised NT/P48 joint venture will consist of Eni (32.5 percent, operator), Petronas (25 percent and Osaka Gas (10 percent). The Evans Shoal gas field is located in the NT/P 48 exploration permit in the Bonaparte Basin.
Project Details: Evans Shoal
Apache Brings Reindeer/Devil Creek Project Online
Dec 7, 2011 – Apache has commenced production from the Reindeer field in the Carnarvon Basin. The delivery of the gas is being processed at the new onshore Devil Creek plant near Karratha. The Reindeer/Devil Creek development includes the installation of an offshore unmanned wellhead platform in the Reindeer field, a 105-kilometer pipeline to shore and the development of the gas plant. The Devil Creek gas plant has a gross production capacity of 215 TJ/day and is initially planned to ramp up to sales of 120 TJ/day. The Reindeer gas field is located in the Carnarvon Basin, offshore Western Australia in waters measuring 203 feet (62 meters) within exploration permit WA-209-P. Apache Corporation holds a 55 percent operating interest, and Santos holds the remaining 45 percent interest.
Project Details: Reindeer-Devil Creek Project

Niko Spuds Stalin Well, Offshore Trinidad

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Niko Resources LTD, an offshore exploration company with headquarters in Calgary, Canada, announced today that it has commenced drilling operations on its first well offshore Trinidad.

The Rowan Gorilla III rig is on location at the Stalin prospect, which is the first of three wells planned for Block 2ab located off Trinidad and Tobago’s eastern continental shelf. The Stalin-1 well is named after the popular calypso great, Black Stalin.

Niko is the operator of the block and has a 35.75% working interest. Partners in the well are Petrotrin with 35% and Centrica Plc with 29.25%. The well is being drilled in 100 feet of water to a total depth of 8800 feet and will test a large anticlinal feature made up of multiple thrust sheets. The reservoir targets are the Oligocene age Angostura sands which are producing in the Angostura field located approximately 23 miles east of the Stalin location.

Niko’s best estimate is a target of 600 to 800 million gross unrisked in-place barrels of oil equivalent.

Source

Total Strikes Oil in Deepwater Angola Block 17/06

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Total announces that its subsidiary, TEPA (Block 17/06) Limited, and Sociedade Nacional de Combustíveis de Angola (Sonangol E.P.), have discovered hydrocarbons in the north-eastern area of the deep offshore block 17/06.

Drilled in a water depth of 445 meters, the Canna-1 well discovered hydrocarbons in reservoir of Miocene age and produced more than 5,000 barrels per day of high quality oil (33° API) during a production test.

Sociedade Nacional de Combustíveis de Angola (Sonangol) is the concessionaire of the Block 17/06. TEPA (Block 17/06) Limited is the operator of the Block 17/06 with a 30% stake. Total’s partners in the block are Sonangol Pesquisa e Produção S.A. (30%), Sonangol Sinopec International (SSI) Seventeen Limited (27.5%), ACREP Bloco 17 S.A. (5%), Falcon Oil Holding Angola S.A. (5%) and PARTEX Oil and Gas (Holdings) Corporation (2.5%).

Total Exploration & Production in Angola

Total is present in Angola since 1953. In Angola, Total operated 460,000 barrels oil equivalent per day (boe/d) in 2010, and its SEC* equity production amounted approximately 163,000 boe/d. This production comes essentially from Blocks 17,0 and 14.

Deep offshore Block 17, operated by Total with a 40% interest, is Total’s principal asset in Angola. It is composed of four major zones: Girassol-Rosa and Dalia, which are currently producing; Pazflor, a project under development for a production start in the second half of 2011; and CLOV (based on the Cravo, Lirio, Orquidea and Violeta discoveries), for which the development was recently launched.

Total is also the operator with a 30% stake in the ultra deep offshore Block 32, on which 12 discoveries were made, confirming the oil potential of the block. Pre-development studies for a first production zone in the central south eastern portion of the block are underway.

In addition, the Angola LNG project for the construction of a liquefaction plant near Soyo is designed to bring the country’s natural gas reserves to market. This project, on which Total holds a 13.6% stake, will be supplied by the associated gas from the fields on Blocks 0, 14, 15, 17 and 18. The project is underway with production expected to begin in 2012.

In Angola, as in all countries where Total operates, the Group is committed to developing the Angolan oil industry while recruiting and providing professional training to local workers. Through its ambitious “Angolanisation” and technology transfer plans, Total has strengthened the local economy and made of Hygiene, Safety and Environment awareness a top priority. Total E&P Angola has developed a transparent and solid corporate social responsibility policy around three main axes: health, education (opening of four high schools in the provinces in 2009) and economic community development.

Original Article

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