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Recap: Worldwide Field Development News (Mar 2 – Mar 8, 2012)


This week the SubseaIQ team added 12 new projects and updated 31 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 – West
Afren Confirms High Quality Oil at Okoro East
Mar 7, 2012 – Afren has completed testing at the Okoro East oil discovery, confirming high-quality API oil of 38 to 40 degrees in excellent reservoir sands. Based on the test data the company expects future horizontal production wells at Okoro East to be capable of yielding between 4,500 to 7,000 bopd per well. The company will drill two production wells using existing facilities in the second half of 2012 and up to eight production wells, under a full field development scenario. Three drill stem tests have been performed and completed, said Afren. The purpose of this test was to obtain fluid samples and pressure data in order to establish reservoir connectivity, heterogeneity and quantify permeability and porosity. The tests have confirmed a high quality 38- to 40-degree API oil, multi-Darcy permeabilities and an average porosity of between 30 percent to 35 percent in the subject reservoirs. The pressure data obtained has helped with the company’s structural understanding of the field and supports the pre-drill volumetric estimates (Pmean STOIIP of 157 million barrels). Based on the test data, the company expects future horizontal production wells at Okoro East to be capable of yielding rates between 4,500 bopd to 7,000 bopd per well. The company intends to drill up to two production wells in 2H 2012 using the free well head slots on the existing Okoro platform, which will be tied-back to the Armada Perkasa FPSO. This production information will allow Amni and Afren to finalize development options with up to eight possible production wells under a full field development.
GSF Monitor Set to Spud Gazelle-P3
Mar 7, 2012 – Rialto Energy announced its plans to drill the first two development wells in the Gazelle Field using the GSF Monitor jack-up rig. The phased development of CI-202 is set to begin with the spudding of Gazelle-P3 followed by Gazelle-P4. An additional two development wells are planned after final investment decision. Two infill wells are planned for 2016.
Project Details: Gazelle
Chariot Inks Deal to Drill Tapir South Prospect
Mar 6, 2012 – Chariot Oil and Gas has signed a contract with AP Moller Maersk for a one-well drilling slot using the Maersk Deliverer (UDW semisub) rig offshore Namibia. The operator expects to spud the Tapir South prospect early April. The prospect is part of the Tapir trend and is located in Northern Block 1811A. The well is located 50 miles (80 kilometers) offshore Namibia in 6,915 feet (2,108 meters) of water with a drilling depth of approximately 16,730 feet (5,100 meters). It is expected to take around two months to drill and will be the first well in Chariot’s four-to-five well exploration program that is planned to take place in 2012 and 2013.
S. America – Other & Carib.
BPZ Further Develops Corvina, Albacora Fields
Mar 5, 2012 – BPZ Energy reported that production from the Corvina and Albacora offshore fields has average about 3,920 bopd from Feb. 2012 to date. The 3D seismic survey acquisition on the offshore Block Z-1 has been underway for four weeks and should be completed in the second quarter of 2012 followed by processing and interpretation of the data. Furthermore, work on the new CX-15 platform continues with installation scheduled for the third quarter of 2012. The CX-15 drilling program, which will be the second platform installation at the Corvina field, will target 23 million barrels of proved undeveloped reserves (PUD). The PUD estimates increased in the 2011 reserve report by one million barrels, stated the operator.
Project Details: Corvina
Europe – North Sea
Wintershall Turns On Taps at K18-Golf Field
Mar 8, 2012 – Wintershall has commenced natural gas production from the K18-Golf field in the Dutch North Sea. Wintershall plans to produce around 1 MMcm/d from the tight gas deposit via a subsea well (subsea completion). A second production well next summer is set to maintain plateau between 1 and 1.4 million cubic meters of natural gas per day. The field was connected via a sea bottom pipeline to the K15-FA platform, about 6.2 miles (10 kilometers) further north. The gas will be treated before being sent via the Wintershall-operated WGT pipeline network. Wintershall has a share of 41.7 percent in K18-Golf. The other participating companies are EBN B.V. (40 percent), NAM (15.9 percent), Tullow Oil (2.2 percent) and Oranje-Nassau Energie (0.2 percent). Wintershall was awarded the concession block K18 in 1983. The natural gas field was discovered in 2005.
Premier Oil P&A Bluebell Prospect
Mar 8, 2012 – Premier Oil will plug and abandon the Bluebell exploration well, 15/24c-10, on Block 15/24 in the UK sector of the North Sea. The well reached a total depth of 7,507 feet (2,288 meters). The Paleocene target was encountered on prognosis; the logs showed excellent sand quality but were water wet.
Project Details: Bluebell
Technip to Conduct FEED for Luva Platform
Mar 8, 2012 – Statoil awarded Technip a lump sum FEED contract for the development of the Luva platform. The contract covers the design and planning for procurement, construction and transportation of a Spar hull and the mooring systems as well as the design of the steel catenary risers. The scope of work includes design and planning for procurement, construction and transportation of a Spar hull and mooring systems, as well as design of the steel catenary risers.
Project Details: Luva
Summit to Begin Drilling Operations at Orchid Prospect
Mar 8, 2012 – Summit Petroleum has commenced well operations at the Orchid prospect in the UK sector of the North Sea, with spudding anticipated in the next couple of days. Orchid is a dual target, four-way dip closure at Tertiary and Chalk level with gross prospective resources associated with the entire prospect estimated internally by Valiant to be 30 mmboe (net 9 mmboe). The well is being drilled by the Sedco 711 (mid-water semisub) and is anticipated to take 35-40 days to complete, once drilling commences.
Project Details: Orchid
Faroe Petroleum Completes Drilling Ops at T-Rex, Bolan
Mar 7, 2012 – Faroe Petroleum has discovered oil in both the T-Rex and Bolan exploration prospects in the Norwegian sector of the North Sea, but not in commercial quantities. The 6406/3-9 well, reached a total depth of 13,725 feet (4,183 meters) within shales of the Lange Formation. The well targeted Lower Cretaceous sandstones of the Lange formation (T-Rex) and Lysing formation (Bolan). T-Rex was the primary target and preliminary results based on extensive coring, wireline logs and pressure data have confirmed the presence of oil, but in a thinner than expected reservoir interval, and the well will therefore not be production tested. Fluid samples were successfully recovered in T-Rex. The quality of the oil was in line with fluids seen in the original discovery well 6506/11-2 (drilled by Statoil in 1991). The Bolan prospect in the shallower Lysing formation also encountered an oil column within an inter-bedded sandstone package. A similar extensive data gathering program was performed on the Bolan prospect as with T-Rex. Additional evaluation is required in order to delineate the areal extent of the oil bearing layers, before any decisions in terms of a further appraisal program can be made.
Project Details: T-Rex
Statoil Touts Success at Skrugard Appraisal
Mar 6, 2012 – Statoil is in the process of concluding the drilling of appraisal well 7220/5-1 on the 7220/8-1 (Skrugard) gas/oil discovery. The discovery was proven in 2011 in Middle and Lower Jurassic reservoir rocks. The objectives of the appraisal well were to confirm the previous volume estimate for the Skrugard discovery and to collect reservoir and overburden data for field development planning. Both objectives have been met, said Statoil. Drilled by Transocean Barents (DW semisub), appraisal well 7220/5-1 has proven a gas column of 85 feet (26 meters) overlaying an oil column of about 158 feet (48 meters). Both column heights and reservoir properties came in as expected. This confirms the previous volume estimate for the Skrugard discovery and the total resource estimate for the Skrugard and Havis structures ranging from 400 to 600 million barrels of recoverable oil. Statoil is currently considering several alternative development concepts for the discovery.
Project Details: Skrugard
Lundin Ups Stake at Brynhild Field
Mar 5, 2012 – Lundin Petroleum has entered into an agreement with Talisman Energy Norge AS to acquire an additional 30 percent interest in PL148, which contains the Brynhild field, offshore Norway. Following the acquisition, Lundin Petroleum will hold a 100 percent interest in PL148. The Brynhild field, which is currently under development, is forecasted to produce first oil in late 2013 at a gross plateau production of 12,000 bopd.
Project Details: Brynhild (Nemo)
Lundin, Det norske Reach Agreement for Luno, Draupne Combined Development
Mar 5, 2012 – Lundin Petroleum and partners Wintershall and RWE Dea have reached an agreement for Det norske-operated licenses PL001B, PL028B, PL242. A plan for development and operation for the Luno field was submitted on January 19, 2012 to the Norwegian Ministry of Petroleum and Energy and includes 15 wells drilled from a jackup. First production is expected in the fourth quarter of 2015. In the coordinated development solution, the partially processed fluids from the Draupne field will be transported from the Draupne platform to the Luno platform for stabilization and export of oil and gas. The combined production from the Luno and Draupne fields will be phased in time with Draupne production planned to start in late 2016 and increasing toward a peak rate in late 2018. The Luno platform design capacity will accommodate in excess of 120,000 bopd and up to 175 MMcf/d when Draupne production is combined with that from the Luno field.
Project Details: Luno, Draupne Project
Statoil Contracts EMAS AMC for Fram H Nord
Mar 5, 2012 – EMAS AMC has received a SURF contract for marine installation and pipe lay from Statoil for the Fram H Nord subsea development. The field is situated in the Troll C/Fram area in the northern part of the North Sea. The Fram H Nord subsea development is the third phase of the development of the Fram field which is tied-back to the Troll C Platform. Fram H-Nord will be developed with one satellite well tied-back to the existing infrastructure at Fram Vest A2 template via twin flowlines and a control and service umbilical. The contract scope includes the engineering, procurement, transport and installation of one 10-inch flexible production and one 4-inch gas injection flowline both 3.2 miles (5.3 kilometers) long, as well as all activities necessary for the installation of the following: integrated template structure and manifold; subsea control umbilical; near-by protection structures; tie-ins of all lines to the Fram H Nord and Fram Vest A2 manifolds plus pre-commissioning/testing; trenching and rock dumping of all line systems; and the supply and installation of protection covers over tie-in areas at Fram H Nord and Fram Vest A2 templates. Engineering, procurement and planning activities will commence immediately, and the offshore work is scheduled to commence in the third quarter of 2013.
Project Details: Troll Area
Asia – SouthEast
Premier Successfully Tests Lama Formation in Anoa Field
Mar 5, 2012 – Premier has successfully tested the Lama formation within the Anoa field on the Natuna Sea Block A. The WL-5 development well was deepened to a total depth of 11,012 feet (3,356 meters) to investigate the exploration potential of the Lama formation within the Anoa field. The well encountered about 300 feet (91 meters) of fractured Lama sandstones. The Lama formation was tested over an interval of 10,658 to 10,770 feet (3,249 to 3,283 meters) and flowed gas at a rate of 17 MMcf/d through a 48/64-inch choke. The results of the test will be intergrated with the log and seismic data to determine the ultimate recoverable resource of this deeper reservoir that will be produced through the Anoa facility. Moreover, the jackup West Callisto (400′ ILC) will move to drill the Biawak Besar prospect on Natuna Sea Block A. The results of this well are expected in April 2012.
N. America – US GOM
Petrobras Brings Cascade Online in GOM
Mar 5, 2012 – Petrobras reported that on Feb. 25, 2012, it commenced production at the Cascade field through the Cascade No. 4 well, which was interconnected to the BW Pioneer FPSO. The Cascade 4 production well was drilled and completed in reservoirs of the Lower Tertiary geological period, which is a promising exploratory maritime boundary of the Gulf of Mexico, at a vertical depth of around 26,247 feet (8,000 meters). The BW Pioneer is the first FPSO to produce oil and gas in the U.S. portion of the Gulf of Mexico, and has the capacity to process 80,000 barrels of oil and 500 Mcm/d.
Project Details: The Greater Chinook Area
Technip to Supply Flexible Pipe for Fletcher, Finucane Development
Mar 5, 2012 – Santos has awarded Technip a flexible pipe supply contract for the Fletcher Finucane oil field development in Western Australia. The contract, which includes project management, engineering and the supply of 19 miles (31 kilometers) of 10.2-inch and 9-inch production flowlines, along with 14 miles (22 kilometers) of 3-inch service lines, will start in April 2012. Delivery is planned for the second semester of 2012.
Project Details: Fletcher/Finucane
BHP Billiton Spuds Tallaganda
Mar 2, 2012 – BHP Billiton has commenced drilling the Tallaganda-1 well at permit WA-351-P offshore Australia. The operator is using the Atwood Eagle (DW semisub) to drill the well. The prospect will test the gas potential of sandstones in the prolific Triassic age, Mungaroo formation, in a well defined horst block as imaged by high quality modern 3D seismic data. The well will be drilled vertically in a water depth of 3,743 feet (1,141 meters) and is expected to take 37 days to drill with a projected total depth of 13,944 feet (4,250 meters).
Project Details: Tallaganda
S. America – Brazil
Petrobras Commences Iracema Well Test
Mar 5, 2012 – Petrobras and partner BG Group have commenced a new well test in the Iracema area of the BM-S-11 concession in the pre-salt Santos Basin. The Cidade de Sao Vicente FPSO was connected to the RJS-647 well in water depths of 7,257 feet (2,212 meters). The FPSO will operate in the area for approximately six months gathering technical information on reservoir behavior and oil flow in the subsea lines amongst other data. During this initial test phase the well is expected to produce at around 10,000 bopd, constrained by facilities. The information gathered will support the development of the final production system in the area, expected to be in operation by the end of 2014 with the installation of the 150,000 bopd capacity FPSO Cidade de Mangaratiba.
Project Details: Iracema
Noble Energy Preps to Drill Pinnacles
Mar 5, 2012 – Delek Group has reported that Pinnacles No. 1 exploratory well, offshore Israel, is due to start soon and is expected to last about five weeks. According to a report prepared by Netherland, Sewell and Associates (NSAI) the estimated unrisked gross prospective gas resources for the Pinnacles Prospect, as of December 31, 2011, is expected to be 25.7 (low) to 78.2 (high). The operator will use the ENSCO 5006 (DW semisub).


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


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.

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
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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