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Anadarko’s First Flow Test Offshore Mozambique Successful

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Anadarko Petroleum Corporation today announced the results of its first flow test offshore Mozambique. The Barquentine-2 well flowed at an equipment-constrained rate of 90 to 100 million cubic feet per day (MMcf/d), with minimal pressure drawdown, providing confidence in well designs that are capable of 100 to 200 MMcf/d.

“The test at Barquentine-2 exhibited exceptional flow characteristics, confirmed the deliverability of this reservoir and indicated a low density of development wells may be sufficient to produce the reservoir,” Anadarko Sr. Vice President, Worldwide Exploration, Bob Daniels said. “Using pre-set gauges in an offset well, we were able to confirm connectivity and reservoir continuity over a distance of more than 3 kilometers. The test also proves the reservoir has very high permeability, meeting the quality specifications for the partnership’s LNG development plans. This is a very encouraging way to start our testing program, which is an important component in the reserve certification process, as we focus on achieving FID (final investment decision) around the end of 2013.”

The Barquentine-2 well is located in water depths of approximately 5,400 feet (1,650 meters) in the Offshore Area 1 of the Rovuma Basin. The drillstem test was conducted by the Deepwater Millennium drillship, which is expected to be mobilized to the Barquentine-1 location for a second flow and interference test in the complex. The 2012 testing program also includes drillstem tests in the Lagosta and Camarao areas to the south of Barquentine.

Anadarko is the operator of the 2.6-million-acre Offshore Area 1 with a 36.5-percent working interest. Co-owners in the area are Mitsui E&P Mozambique Area 1, Limited (20 percent), BPRL Ventures Mozambique B.V. (10 percent), Videocon Mozambique Rovuma 1 Limited (10 percent) and Cove Energy Mozambique Rovuma Offshore, Ltd. (8.5 percent). Empresa Nacional de Hidrocarbonetos, E.P.’s 15-percent interest is carried through the exploration phase.

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Recap: Worldwide Field Development News (Feb 17 – Feb 23, 2012)

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This week the SubseaIQ team added 14 new projects and updated 47 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 Petroleum Contracts 3D Surveys for Italy Permits
Feb 20, 2012 – Northern Petroleum announced the completion of a 2D seismic survey in late 2011 and has contracted to acquire two 3D seismic surveys on permits F.R39.NP and F.R40.NP, subject to environmental consents. The area is recognized by Northern to be highly potential for the production of both oil and gas with 2P reserves having been independently attributed to the Giove and Rovesti oil discoveries. This view is perhaps reinforced by the recent on-site activities to place the nearby Aquila oil field back into production using a newly converted Floating Production and Storage Offloading vessels, stated the operator.
Noble Energy Interprets 2D Seismic Data from Rhone Maritime Concession
Feb 17, 2012 – Noble Energy and Melrose Resources are nearing completion of interpreting 2D seismic survey, acquired in early 2010, over the Rhone Maritime concession offshore France. The consortium plans to meet in the coming weeks to review the interpretation and discuss future work plans. The acreage, covering an area of about 3 million acres (12,500 square kilometers) in the Rhone delta in the French Mediterranean, has both Pre-Messinian and Post-Messinian hydrocarbon potential.
Africa – West
APCL Finds Oil at Narina Prospect
Feb 21, 2012 – African Petroleum has made a “transformational” oil discovery at the Narina-1 exploration well in Block LB-09 offshore Liberia. The well was drilled to a total depth of 15,912 feet (4,850 meters), encountering 105 feet (32 meters) of high-quality light oil pay in two separate intervals. The well found 69 feet (21 meters) of pay in good quality Turonian submarine fan system and 36 feet (11 meters) in a deeper Albian sand with secondary potential. At the Turonian level, the well appears to have clipped the edge of a potentially expansive fan system covering an area of 61,776 acres (250 square kilometers). The operator said follow-up appraisal drilling is required to determine field commerciality, but the early indications are extremely positive and, assuming a moderate thickening of the reservoir away from the discovery well, should underpin the pre-drill estimate of 500 MMbbls recoverable.
Project Details: Narina
Africa – Other
Anadarko, Cove Energy Hit Additional Gas Pay in Mozambique
Feb 21, 2012 – Anadarko has encountered additional pay at the Lagosta-3 appraisal well — a further 577 net feet (176 meters) of natural gas pay offshore Mozambique. The well found high-quality gas sands not well imaged by seismic data, thus confirming the gas accumulation to the western limits of WLBC gas complex, into what was an unknown area. Anadarko said that pressure readings have confirmed important reservoir continuity of Lagosta 3 to Lagosta 1 and 2, and to the Windjammer/Camarao wells situated further north. The operator is continuing towards making a final investment decision on the development in 2013. Furthermore, the operator is preceding to drill-stem test the Barquentine-2 well and is preparing to drill the Barquentine-4 appraisal well.
Project Details: Lagosta
Statoil Spies Natural Gas Offshore Tanzania
Feb 17, 2012 – Statoil confirmed that the Zafarai-1 well in Block 2 offshore Tanzania has encountered natural gas in a good-quality reservoir. The operator said it is too early to give any indication of size and commerciality. Drilling operations are ongoing and should take about three months to complete. The well is being drilled by the Ocean Rig Poseidon (UDW drillship) to a total depth of 16,900 feet (5,150 meters). Zafarai-1 is the first well drilled in the license, which covers an area of about 1.3 million acres (5,500 square kilometers). The water depth of the site is 8,470 feet (2,582 meters).
Project Details: Zafarai
N. America – US GOM
Apache to Spud Parmer in 2Q12
Feb 22, 2012 – Apache plans to spud the Parmer deepwater prospect, located in the GOM, in 2Q12. The prospect resides in Green Canyon Block 823, which Apache operates with a 50 percent interest.
Stone Energy Announces Plans for Pompano Field
Feb 22, 2012 – Stone Energy announced its three-year plan for the Pompano field in the GOM, which entails several workover/recompletion projects during 2012, followed by a platform drilling program projected for 2013. Additionally, the three-year plan calls for a drilling program utilizing a floating drilling rig to commence in 2014/2015. The deepwater field commenced production in 1996.
Project Details: Pompano
Technip to Install Subsea Equipment for Tubular Bells Development
Feb 20, 2012 – Hess Corporation has awarded Technip a lump sum contract for the development of the Tubular Bells field in the GOM. The contract covers the design, engineering, fabrication and subsea installation of more than 28 miles (45 kilometers) of flowlines, steel catenary risers, pipeline end terminations, piles and structures. Offshore installation is scheduled for completion during the first half of 2013.
Project Details: Tubular Bells
Anadarko Hits Additional Pay in Heidelberg
Feb 17, 2012 – Anadarko Petroleum has successfully appraised the Heidelberg-2 appraisal well, located in Green Canyon Block 903 in the deepwater GOM. Heidelberg-2 encountered about 250 net feet (76 meters) of oil pay in high-quality Miocene sands. The appraisal well was drilled to a total depth of 31,030 feet (9,458 meters) in about 5,000 feet (1,524 meters) of water, about 1.5 miles (2.4 kilometers) south and 550 feet (168 meters) structurally updip from the Heidelberg discovery well. Log and pressure data from the appraisal and discovery wells indicate excellent quality, continuous and pressure-connected reservoirs with the same high-quality oil. Anadarko plans to immediately sidetrack the well to evaluate the down-dip extent of the field, and plans to initiate pre-FEED activities to prepare for sanctioning a development plan, stated the operator.
Project Details: Heidelberg
Australia
Woodside Hits Gas in Ragnar-1
Feb 22, 2012 – Woodside Petroleum has made a discovery in the Ragnar-1 well offshore Australia in permit WA-430-P. The well intersected 623 feet (190 meters) of gross gas.
Europe – North Sea
Lansdowne Pleased with Amergin 3D Results
Feb 23, 2012 – Lansdowne has interpreted 3D seismic data over its Amergin prospect in the North Celtic Sea basin. The data has confirmed the presence of a robust rotated tilted fault block. The primary targets are for oil in the Cretaceous Basal Wealden sands, which are currently being appraised at the Barryroe 48/24-10Z well some 25 miles (40 kilometers) to the east, and the Upper Jurassic sands that are oil bearing in the Helvick field, 75 miles (120 kilometers) to the northeast. Prospective resource estimates for Amergin have increased from 62 million barrels of oil to 231 Mmbo reflecting additional prospectivity within the Cretaceous Wealdean sands as well as an upgrade to the estimates for the Basal Wealden (an increase of 79 Mmbo to 104 Mmbo) and Upper Jurassic (up by 10 Mmbo to 47 Mmbo). The Amergin prospect lies in License 5/08, which incorporates Blocks 47/25, 48/21 and 48/22. The blocks cover an area of about 110,950 acres (449 square kilometers). Landsowne Oil & Gas operates the license.
Project Details: Amergin
Nexen Connects Blackbird Umbilical to Aoka Mizu FPSO
Feb 23, 2012 – Nexen has successfully connected the Blackbird field umbilical tieback to the nearby Ettrick field’s Aoka Mizu FPSO in the UK sector of the North Sea. First Subsea conducted a front-end engineering and design (FEED) study to assess the ease of retrofitting an Oceaneering Multiflex power umbilical to the underside of the FPSO Aoka Mizu, without the need of a diver. A Type II bend stiffener connector (BSC) was selected to connect the electrical cable umbilical to a 20-inch-diameter J-tube on the FPSO.
Project Details: Ettrick
Lansdowne Upgrades Midleton Prospective Resources
Feb 23, 2012 – Lansdowne has interpreted 3D seismic data over its Midleton prospect in the North Celtic Sea basin. The data has confirmed that Midleton is a four-way dip closed faulted anticline at the primary Lower Cretacous “A” Greensand level. This sand is the main reservoir in the nearby Kinsale Head gas field and the sole producing reservoir in the nearby Ballycotton gas field. Prospective resource estimates for Midleton have increased from 56 Bcf of gas to 268 Bcf, with new potential seen in the Upper Wealden sands (94 Bcf). The primary Lower Cretaceous “A” sand has also been revised upwards from 56 Bcf to 174 Bcf.
Project Details: Midleton
Technip Bags Compression Contract for Asgard Field
Feb 22, 2012 – Technip has received a contract to oversee the marine operations of the world’s first seabed gas compression facility on the Asgard field, which is expected to increase recovery from Mikkel and Midgard by roughly NOK 278 MMbbl of oil equivalents. The contract for marine operations is one of several major contracts awarded in connection with the decision to adopt new technology in order to increase recovery and maintain production on the Asgard field. Asgard seabed gas compression will start up in 2015.
Project Details: Asgard
Statoil to Use Statfjord B Platform Beyond Design Lifetime
Feb 21, 2012 – The Petroleum Safety Authority Norway granted Statoil consent to use the Statfjord B platform beyond its design lifetime. The company has applied for a 20-year lifetime extension from Aug. 31, 2011.
Project Details: Statfjord Area
Xcite Upgrades Bentley Field’s Oil Reserves
Feb 20, 2012 – Xcite Energy has upgraded its oil reserves at the Bentley field, located in the UK sector of the North Sea. TRACS International Consultancy, an independent reserves auditor, estimated that oil reserves of the type 1P, 2P and 3P for the core area of Bentley are approximately 99 million, 116 million and 140 million barrels of oil, respectively. The operator plans to begin developing the field this year, after completing “significant work” in the latter half of 2011 to prepare for the Bentley Phase 1A work program in 2012. The field development plan for Bentley, comprising of Phase 1B and Phase 2, was submitted for approval to the Department of Energy and Climate Change in the final quarter of 2011.
Project Details: Bentley
North Sea Islay Production To Start In March
Feb 20, 2012 – Total expects to start gas production at the Islay field in the Norwegian sector of the North Sea next month, reported Dow Jones Newswires. Islay will connect to the Alwyn facility and is expected to produce at a production rate of 2.5 MMcm/d plus associated condensates.
Project Details: Greater Alwyn
Jette Ready and Awaiting Development
Feb 17, 2012 – Det norske received approval to proceed with the development of Jette, which contains 14 million barrels of oil equivalents, based on a 30 percent recovery rate. Daily production during the first year will constitute approximately 14,000 barrels. The estimated development costs of Jette amount to approximately 2.5 billion NOK. Production is scheduled to commence during Q1 2013. The field will be developed and operated by Det norske with day-to-day operations overseen by ExxonMobil. Det norske???s partner in the Jette development is Petoro.
Project Details: Jette (Jetta)
Black Sea
ExxonMobil, OMV Potentially Find Large Gas Pay in Black Sea
Feb 22, 2012 – ExxonMobil Exploration and Production Romania and OMV Petrom SA have made a potentially “significant” gas discovery in the Black Sea, offshore Romania. The Domino-1 exploration well encountered 232 feet (70.7 meters) of net gas pay, resulting in a preliminary estimate for the accumulation ranging from 1.5 to 3 Tcf or 42 to 84 Bcm. Drilling operations started at year-end 2011 and the total depth of the well is expected to be more than 9,843 feet (3,000 meters) below sea level. The consortium is planning new 3D seismic acquisition during 2012 with the results from the seismic study and evaluation of drilling to determine the next needed steps.
Project Details: Domino
Melrose Plans to Conduct 2D, 3D Survey Offshore Romania this Summer
Feb 17, 2012 – Melrose Resources received tenders from 12 contractors for the acquisition of 559 miles (900 kilometers) of 2D seismic data and 321,237 acres (1,300 square kilometers) of 3D seismic data on the Muridava and Est Cobalcescu blocks, situated offshore Romania. The contract is expected to be negotiated and awarded by the end of March with a view to acquire the survey over the summer months. Melrose acquired the blocks in March 2011.
Melrose Resources Processing, Interpreting 3D Seismic Data at Galata Block
Feb 17, 2012 – Melrose Resources is processing and interpreting new 3D seismic data acquired over the Galata block offshore Bulgaria, which is expected to be completed by the end of April 2012. The data will be used to update the prospect and lead inventory and to help formulate future drilling plans for the central area of the concession. The Galata Block houses the Galata and Kaliakra fields in the Black Sea.
Project Details: Galata Area

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UK: Shell Tables USD 1.56 bln Bid for Cove

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Shell’s subsidiary, Shell Bidco has placed a bid £992.4 million (USD 1.56 billion) to acquire the entire issued and to be issued share capital of UK headquartered Cove Energy.

The bid comes one month after the decision announced by Cove to conduct a formal sale process for the company. Shell Bidco is a participant in the formal sale process and, as a result of such participation, Shell Bidco and Cove are near agreement on the full terms and conditions of a recommended cash offer by Shell Bidco for Cove. According to the report on Cove Energy’s website, Shell will pay 195 pence for each Cove share.

Still, the making of the Firm Intention Announcement is subject to, and conditional upon, the receipt of written consent of the Republic of Mozambique’s Minister of Mineral Resources which is related to Cove’s 8.5 per cent  participating interest in the Mozambique Rovuma Offshore Area 1 Block (the “Rovuma Area 1 Interest”),

Cove to assist with approvals

East Africa focused Cove has agreed, for as long as the Board of Cove expects to recommend the Proposed Offer, to assist Shell Bidco in relation to obtaining any required governmental consents, including the Mozambique Consent, as soon as reasonably practicable after the release of this announcement.

Shell’s decision to announce this Proposed Offer for Cove fits with Shell’s strategic aim to drive forward with its investment programme, to deliver sustainable growth and to provide competitive returns to shareholders.

East Africa is a major prospective hydrocarbon province, which has seen a significant increase in exploration activity in recent years. Shell already has interests in Tanzania, and the acquisition of Cove would mark Shell’s entry into exciting new hydrocarbon provinces in Kenya and Mozambique, with significant potential for new LNG from recent gas discoveries offshore Mozambique, and further complementary exploration positions in East Africa. In Mozambique, the Rovuma offshore basin is a frontier exploration area that holds large resources of natural gas reserves, suitable for LNG projects. According to Cove, the play represents the potential for 30+ tcf and 6 LNG trains.

Mozambique prosperity

Shell understands that bringing these resources on stream is a strategic priority for the Mozambican Government in order to foster further economic and community development in the country, and Shell is committed to being a partner in that process,” said Shell in a statement.

Shell is one of the world’s largest LNG producers, with one of the most diverse LNG portfolios and access to strategic global markets with equity sales volumes of 18.83 mtpa of LNG in 2011. Shell holds the largest equity share of LNG capacity among IOCs – currently holding some 20.5 mtpa of equity LNG capacity on-stream. Adding Cove’s assets to Shell’s portfolio would strengthen and further diversify Shell’s existing global LNG portfolio of production and development projects. Furthermore, Shell has set industry records for LNG plant construction times and operational start-ups, safely delivering projects from concept to first production for/with its partners. In joint ventures with partners, Shell currently produces LNG in Australia, Brunei, Malaysia, Nigeria, Oman, Russia and Qatar, with excellent production reliability performance achieved at all these plants.

In addition to Shell’s technical expertise, its marketing and shipping know-how is designed to enable the delivery of long-term added value together with project partners. Shell has access to the key LNG markets of Europe, Asia Pacific and  North America. In 2011, Shell joint ventures supplied more than 30 per cent. of global LNG volumes. Shell would also bring its extensive project finance experience across the LNG value chain. Shell’s experience in LNG project finance extends over many projects, e.g.: Oman LNG, Nigeria LNG, Qatargas 4, Sakhalin.

Shell management said it was confident that its innovative technologies, leading plant designs, unmatched LNG operational experience and proven commercialisation strategies, combined with the experience of the operator of the Mozambique Rovuma Offshore Area 1 Block and the joint venture partners can add significant value to the project.

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Anadarko Finds Hydrocarbons Offshore Sierra Leone

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Anadarko’s Jupiter-1 exploration well in Block SL-07B-11 offshore Sierra Leone has encountered hydrocarbons. This has been confirmed by the results of drilling, wireline logs and samples of reservoir fluids.

The well, located over 25 kilometres west of the Mercury-1 well which discovered oil in the block, intersected 30 metres of hydrocarbon pay in the primary Upper Cretaceousobjective and did not encounter a hydrocarbon water contact. The well has been preserved for possible future re-entry, as the area is likely to require additional evaluation.

Jupiter-1 was drilled by the Transocean Discoverer Spirit drillship to a total depth of 6,465 metres in a water depth of 2,199 metres. On completion of operations, the drillship will move 15km northeast to the Mercury-2 well which will target several reservoir levels including extensions of the oil accumulations discovered by the Mercury-1 well.

Anadarko (55%) is Operator of offshore Block SL-07B-11 along with partners Repsol (25%) and Tullow (20%).

Angus McCoss, Exploration Director of Tullow, commented today:

“Jupiter is the third discovery in the Liberian Basin by Tullow and its Partners and provides further support for the stratigraphic play in the region. The presence of a working petroleum system producing gas and light oil in the basin is encouraging. Our technical teams will continue evaluating prospectivity across our significant regional acreage position. We will further test the play through the drilling of Mercury-2 in Sierra Leone and Kosrou-1 which is currently drilling in Côte d’Ivoire.”

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Anadarko Strikes More Mozambique Gas

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Anadarko Petroleum Corporation today said that its latest appraisal well offshore Mozambique, Lagosta-3, encountered approximately 577 total net feet (176 meters) of natural gas pay in multiple zones.

The partnership’s successful appraisal drilling continues to confirm and expand the world-class nature of this massive natural gas accumulation offshore Mozambique,” said Bob Daniels, Anadarko Sr. Vice President, Worldwide Exploration. “The Lagosta-3 well encountered high-quality sands and successfully confirmed an area of the field that was not as well-imaged in our seismic data due to overlying faulting. Additionally, we continue to accelerate our operational learning curve, safely drilling the last two wells faster and more cost effectively than the preceding wells. We expect these drilling-efficiency improvements to translate into significant cost savings over time, as we continue to advance the project.”

The Lagosta-3 well is located about 2 miles (3 kilometers) west of the Lagosta-1 discovery well and 9 miles (15 kilometers) south of the Camarao-1 well. It was drilled to a total depth of approximately 13,715 feet (4,180 meters) in water depths of approximately 4,606 feet (1,404 meters) and will be suspended while the rig is mobilized to drill the Barquentine-4 appraisal well. Anadarko has two deepwater drillships operating in the discovery area offshore Mozambique, the second of which is now on location at the Barquentine-2 well preparing for drillstem testing.

Anadarko and its partners are now advancing a commercial liquefied natural gas (LNG) development in Mozambique that is initially expected to consist of at least two 5-million-tonne-per-annum liquefaction trains.

Anadarko is the operator of the 2.6-million-acre Offshore Area 1 with a 36.5-percent working interest. Co-owners in the area are Mitsui E&P Mozambique Area 1, Limited (20 percent), BPRL Ventures Mozambique B.V. (10 percent), Videocon Mozambique Rovuma 1 Limited (10 percent) and Cove Energy Mozambique Rovuma Offshore, Ltd. (8.5 percent). Empresa Nacional de Hidrocarbonetos, E.P.’s 15-percent interest is carried through the exploration phase.

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Eni Reports Another Giant Gas Discovery Offshore Mozambique

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Eni announces a new giant natural gas discovery at the Mamba North 1 prospect, in Area 4 Offshore Mozambique, encountering a mineral potential of 212.5 billion cubic meters (7.5 tcf) of gas in place.

This new discovery, in addition to the Mamba South discovery from October 2011, further increases the potential of the Mamba complex in the Area 4. It is estimated that the total volume of gas in place reaches now about 850 billion cubic meters (30 tcf).

The Mamba North 1 discovery, located in water depths of 1,690 meters, reaches a total depth of 5,330 meters and is located approximately 23 Km north of Mamba South 1 discovery and 45 Km off the Capo Delgado coast. The discovery well encountered a total of 186 meters of gas pay in multiple high-quality Oligocene and Paleocene sands.

During the production test, the first performed at offshore Rovuma, the well produced high quality gas with flow rates, constrained by surface facilities, of about 1 million cubic meters a day and minor volumes of condensates. In a final production completion configuration, estimated gas production per well is expected to reach over 4 million cubic meters a day.

During 2012, Eni plans to drill at least other five wells in nearby structures to assess the upside potential of Mamba Compex.

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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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Another Success Offshore Mozambique for Anadarko

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Anadarko​ today announced 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 Camarao well, encountered 777 total net feet (237 meters) of natural gas pay in multiple zones.

“This is the largest pay count of any well in the complex to date, and it seems fitting that our seventh successful well in the discovery area would encounter 777 net feet of pay,” said Bob Daniels, Anadarko Sr. Vice President, Worldwide Exploration.

“These excellent results continue to support our recoverable resource estimates of 15 to 30-plus Tcf (trillion cubic feet) of natural gas in the discovery area on our block, as well as provide additional information that will be incorporated into our models to help determine the optimal subsea development plans for the complex. In addition, a second deepwater drillship, the Deepwater Millennium, has arrived in Mozambique to begin an accelerated testing program that will include installing observation gauges and conducting several drillstem tests, as we remain on track to reach a final investment decision for this project in 2013.”

The Lagosta-2 appraisal well was drilled to a total depth of approximately 14,223 feet (4,335 meters) in water depths of approximately 4,813 feet (1,467 meters) in the Offshore Area 1 of the Rovuma Basin. The partnership 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 deepwater drillship will be mobilized to drill the Lagosta-3 appraisal well.

Anadarko is the operator of the 2.6-million-acre Offshore Area 1 with a 36.5-percent working interest. Co-owners in the area are Mitsui E&P Mozambique Area 1, Limited (20 percent), BPRL Ventures Mozambique B.V. (10 percent), Videocon Mozambique Rovuma 1 Limited (10 percent) and Cove Energy Mozambique Rovuma Offshore, Ltd. (8.5 percent). Empresa Nacional de Hidrocarbonetos, E.P.’s 15-percent interest is carried through the exploration phase.

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