Blog Archives

Worldwide Field Development News Sep 1 – Sep 7, 2012

This week the SubseaIQ team added 0 new projects and updated 8 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.

Europe – North Sea

Valiant Considering Alternative Development Options for Crawford

Sep 6, 2012 – Valiant Petroleum, along with its joint venture partners, is actively pursuing other development solutions for the Crawford discovery in the UK North Sea; the partners concluded the original development plan created by Fairfield is not the best way to proceed. A broad range of development options are under consideration for both surface and subsurface. The timeframe for a fully supported field development plan may extend into 2013.

Project Details: Crawford

Norway’s PSA Approves Geite Permit

Sep 6, 2012 – The Petroleum Safety Authority Norway has given its consent to Det norske to drill their Geite prospect in PL 497. Well 7/11-13 will be drilled using the Maersk Guardian (350′ ILC). Drilling is estimated to take approximately 80 days, but could take as long as 135 days if a sidetrack is drilled.

Project Details: Geite

Lundin Receives NPD Nod for Johan Sverdrup Sidetrack

Sep 6, 2012 – Lundin Petroleum has received approval from the Norwegian Petroleum Directorate to drill an appraisal well at the Johan Sverdrup discovery located in production license 501. Well 16/2-13A will be drilled using the Transocean Arctic (mid-water semisub).

Project Details: Johan Sverdrup

Ithaca Successfully Completes Hurricane DST

Sep 6, 2012 – Ithaca Energy has completed a successful drill stem test (DST) on the Andrew sandstone interval in the Hurricane appraisal well, achieving a maximum flow rate of approximately 24 MMscf/d with associated condensate of 1,200 bopd. The well is being suspended as a future producer from the Andrew reservoir along with the capability to produce from the Rogaland reservoir. During the 24-hour test period, the Andrew interval achieved an average gross flow rate of approximately 17 MMscf/d with associated condensate of 870 bopd from a half-inch choke. Plans are already underway to assess development options.

Project Details: Stella/Harrier

EMAS AMC Wins Cable Installation Work at Troll

Sep 6, 2012 – EMAS AMC has been awarded a contract by ABB for the installation of subsea power cables at the Troll A Platform located offshore Norway. The work scope includes the installation of one HVAC cable and two circuits of HVDC subsea cable from Troll A to the land station Kollsnes. These new cables will provide power to run two compressor drive systems, which will improve production capacity and extend the platform’s lifespan. The Lewek Connector is scheduled to begin operations during 2Q 2014. EMAS AMC is the subsea construction division of Ezra Holdings and the contract was awarded as part of a large strategic cooperation agreement between the two companies.

Project Details: Troll Area

Asia – SouthEast

South Kecapi Expected to Spud by Year End

Sep 6, 2012 – Salamander Energy is expected to spud its South Kecapi prospect by the end of 2012. The Ocean General (mid-water semisub) has been selected to drill the well. Gross mean unrisked resource potential for South Kecapi is 274 Bcf. Salamander Energy estimates its odds of success are 44 percent.

Partners Select Prospect to Drill on Thailand Block G2/48

Sep 5, 2012 – Pearl Oil along with its JV partner, Rayong Offshore Exploration, has selected the Sainampeung-1 prospect as the optimal location to test the G2/48 concession located in the Gulf of Thailand. Sainampueng-1 will be drilled in 4Q 2012 using the Ensco 85 (300′ ILC). Estimates suggest the mean unrisked prospective resources to be 10 million stock tank barrels (MMstb) with a high side of up to 27 MMstb (P10). Sainampueng-1 has the potential to open a new basin with significant follow-up potential.

Project Details: Sainampueng


ConocoPhillips Intersects Primary Objective at Boreas-1

Sep 6, 2012 – Boreas-1 has intersected the primary reservoir objective and the drilling assembly is being pulled so that coring operations can commence. The well intersected a sand interval characterized by a Rate of Penetration increase, sandy drill cuttings and an increase in the mudlog gas readings indicating a potential gas bearing reservoir. Coring operations will be undertaken to allow more extensive analysis of rock properties in potential reservoir intervals. Production testing will be undertaken if hydrocarbon bearing sands are encountered and confirmed by the wireline logging and the pressure and sampling programs.

Project Details: Boreas

Farm-Out Negotiations Open for La Bella

Sep 4, 2012 – WHL Energy announced they have formally commenced the farm-out process on its VIC/P67 oil and gas permit in the offshore Otway Basin off the Victorian coast of Australia. Strong industry interest to participate in the development of the permit has prompted this Australian-based operator to open a data room in Perth, providing potential partners with access to past exploration and study data from previous operators as well as WHL Energy. The farm-out process is expected wrap up by the end of 2012. The VIC/P67 permit is located approximately 124 miles (200 km) West-Southwest of Melbourne and is wholly owned by WHL Energy.

Project Details: La Bella

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


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

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

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

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

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

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

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


Norway: Little Knowledge on Northeastern Barents, NPD Says


The Norwegian Government has decided that the Norwegian Petroleum Directorate will map the geology in the northeastern part of Norway’s new sea area in the Barents Sea. According to the plan, the seismic surveys will start this summer and continue into 2013. This will provide important knowledge regarding possible oil and gas resources in this area.

“We have very little knowledge concerning the geology in the northeastern Barents Sea. In order to know more about the resource potential, we need more data,” says Sissel Eriksen, exploration director in the Norwegian Petroleum Directorate.

On 15 September 2010, Norway and Russia signed the agreement relating to maritime demarcation and cooperation in the Barents Sea and Arctic Ocean. The agreement entered into force on 7 July 2011.

On the Norwegian side, the Government has started an opening process with the aim of awarding production licenses in the southeastern sector of the Barents Sea. The geological mapping started last summer and will continue until this summer.

Earlier this year, the NPD entered into contracts regarding two vessels that will acquire seismic data both in the southeastern sector of the Barents Sea, in the sea area around Jan Mayen and in Nordland IV and V this summer.

“The plans to also map the northeastern sector of the Barents Sea mean that we need more capacity to acquire seismic. This assignment has been submitted for tender,” says Eriksen.


Recap: Worldwide Field Development News (Jan 20 – Jan 26, 2012)


This week the SubseaIQ team added 10 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.

Europe – North Sea
Duart Field Shut-In
Jan 26, 2012 – Bridge Energy stated that the Duart field is currently shut-in with production expected to restart in mid-March. The satellite field is located on UK Block 14/20 in the North Sea about 116 miles (186 kilometers) northeast of Aberdeen, Scotland.
Det norske to Drill Geite Prospect 2Q 2012
Jan 26, 2012 – Det norske announced plans to commence exploratory drilling in licenses PL 497/497B, in the Norwegian sector of the North Sea. Geite, located in a water depth of 262 feet (80 meters), is considered a large 4-way fault dependent closure. The operator plans to drill the prospect in 2Q12.
Project Details: Geite
Valiant, Antrim to Develop Fionn Field
Jan 25, 2012 – Antrim Energy and Valiant Petroleum have signed an agreement to proceed with early installation of subsea facilities for the development of the Fionn field in the UK sector of the North Sea. Fionn, located in Block 211/22a, was formerly called Central Causeway fault block. In December 2011, the UK Department of Energy and Climate Change assigned separate field designations to the Fionn field and the Causeway field, the latter containing the two fault blocks previously referred to as the East Causeway and Far East Causeway fault blocks. A Field Development Plan for the Causeway field was approved by DECC, with first oil expected in mid-2012. Under the terms of the Fionn Agreement, various subsea facilities will be installed during the first half of 2012 in conjunction with the installation of facilities for the Causeway field as a pre-investment for the future tie-in of Fionn to minimize development costs. Valiant will finance Antrim’s share of these costs. For three months following first oil from Causeway, Antrim has the option either to either withdraw from the Fionn project, or confirm its participation by paying its 35.1 percent share of the pre-investment outlay. Operator Valiant Causeway will likely submit a development plan for Fionn to DECC during the current quarter. It is planned that Fionn production will be combined with Causeway production, transported for processing to the Cormorant North platform, and exported to the Sullom Voe terminal for sale. First oil from Fionn is anticipated in mid-2013.
Project Details: Causeway
Total Submits Hild PDO to Norwegian Authorities
Jan 25, 2012 – Total has submitted a Plan for Development and Operation to the Norwegian Petroleum Directorate for the Hild field in the Norwegian sector of the North Sea. The field has estimated recoverable reserves of 1 Bboe. The development calls for an integrated wellhead, living quarters and production facility with a life expectancy of 30 years. The facility will be designed for remote control from an onshore base in Stavanger via an undersea cable from Kollsnes. It will also receive power from land. Oil will be sent by pipeline to a contracted storage vessel for processing before loaded onto shuttle tankers. The ship, which is planned to receive power from the production facility, can store up to 620,000 barrels of oil. Production is slated to commence in 2016. Hild is located in a water depth of 328 to 394 feet (100 to 120 meters).
Project Details: Hild
Nautical Divests 25% Stake in Kraken to EnQuest
Jan 24, 2012 – Nautical Petroleum will divest a 25 percent stake in the Kraken discovery (Petroleum License P1077) to EnQuest. Subject to the approval of the joint venture partners and the Department of Energy and Climate Change (DECC), EnQuest will become the operator of blocks 9/2b & 9/2c. The deal will involve Nautical receiving a carry on in its future expenditure on the Kraken field of up to $240 million, consisting of $150 million firm carry and a contingent carry of up to $90 million. The value of the contingent carry will be calculated by reference to a determination of the gross 2P reserves in blocks 9/2b and 9/2c. The reserve determination will take place during the development drilling phase. In addition to the disposal of a 25 percent interest in Kraken, Nautical will also divest interests in exploration blocks in the Greater Kraken area. EnQuest will receive a 10 percent interest in the P1575 license (Blocks 9/6a and 9/7b) and a 15 percent interest in the P1573 and P1574 licenses (Blocks 3/22a and 3/26). Krakan spans Blocks 9/2b and 9/1a in the UK sector of the North Sea.
Project Details: Kraken
E.ON Comes Up Dry at PL 350
Jan 23, 2012 – E.ON Ruhrgas has completed the drilling of wildcat well 6507/6-4 S and is in the process of completing the drilling of wildcat well 6507/6-4 A. Both wells are dry. The objective of wells 6507/6-4 S and 6507/6-4 A was to prove petroleum in Upper Triassic and Permian reservoir rocks, respectively. Well 6507/6-4 S encountered Upper Triassic reservoir rocks with reservoir quality as expected, while well 6507/6-4 A did not encounter the expected reservoir rocks. Extensive data acquisition has taken place at both wells and sampling was carried out. This is the first time drilling has occurred in PL 350. The wells will now be permanently plugged and abandoned.
Staoil Gets Govt Nod for Skuld Fast-Track Development
Jan 20, 2012 – The Ministry of Petroleum and Energy has greenlighted the plan for development and operation of Skuld, a fast-track development tied-in to the Norne field in the Norwegian sector of the North Sea. The field will be developed by three subsea templates with six production wells and three water injectors connecting to the Norne FPSO through a 14-inch-diameter production flowline and umbilical. The field is scheduled to come online by late 2012. Recoverable reserves in Skuld are estimated at 90 MMboe, primarily oil.
Project Details: The Greater Norne Area
Asia – SouthEast
AWE Acquires Acreage in Natuna Sea
Jan 26, 2012 – AWE Limited has executed a sale and purchase agreement with a Genting Berhad subsidiary to acquire a 100-percent interest and operatorship in two production sharing contracts offshore Indonesia for $39 million. Under the terms of the agreement, a wholly owned subsidiary of AWE will acquire assets that include an undeveloped oil field with an estimated 76 MMbbl of recoverable oil. The two PSCs, the North West Natuna PSC and the Anambas PSC, are located in the Natuna Sea in 230 to 295 feet (70 to 90 meters) of water. The NWN PSC contains the undeveloped Ande Lumut oil field, which is estimated to contain 76 MMbbl of recoverable heavy oil, and three exploration and appraisal wells. The Anambas PSC contains the Anambas gas field, discovered in 2006, together with a number of additional exploration prospects within an offshore area containing significant gas development and pipeline infrastructure. The transaction is effective from Jan. 1, 2012 and is anticipated to be complete by February 2012. The purchase will be funded by cash reserves and proceeds from part of AWE’s stake sale in the BassGas Project.
Nido to Acquire 2D Data over Service Contract 58
Jan 25, 2012 – Searcher Seismic, on behalf of the Service Contract 58 Joint Venture, is acquiring 621 miles (1,000 kilometers) of new 2D seismic data over the greater Bikuda ??? Bulador prospect area in the northern sector of the area. The prospects were high-graded by subsurface work performed in 2011. The survey will help to mature these prospects to drillable status, so they can be considered as candidates to meet the sub-phase 3 commitment well due before January 2014. The survey is expected to commence in the near future. Service Contract 58, operated by Nido with a 50 percent stake, is a large deepwater block covering approximately 3.3 million acres (13,440 square kilometers) that lies immediately outboard of the giant Malampaya gas field. No wells have been drilled in the block to date. Water depths are in excess of 3,281 feet (1,000 meters) over most of the block.
MEO Australia Creating POD for Seruway PSC
Jan 24, 2012 – MEO Australia says it is working on a variety of activities aimed at maturing a Plan of Development (POD) for the Gurame gas discovery within the Seruway PSC offshore Indonesia. This POD maturation, coupled with the Kuala Langsa discovery and the improved definition of the Ibu Horst exploration prospects will underpin its future plans to attract a farm-in partner for the Seruway block. MEO has committed to acquiring 172,974 acres (700 square kilometers) of 3D seismic and to drill a well by the end of 2012. The Seruway PSC covers an area of 898,228 acres (3,635 square kilometers) and contains two gas discoveries – Gurame and Kuala Langsa – including several exploration opportunities.
Asia – Far East
ConocoPhillips Reaches Settlement Agreement Related to Peng Lai Oil Spill
Jan 25, 2012 – ConocoPhillips and the China National Offshore Oil Corp. have reached an agreement with China’s Ministry of Agriculture to resolve issues related to the June 2011 incidents at the Peng Lai 19-3 field in Bohai Bay. The company will make a compensation payment of $160 million to settle public and private claims of potentially affected fishermen and bay communities from the oil spill. ConocoPhillips will also designate a portion of its $16 million environmental fund to improve fishery resources. Peng Lai is located on the Bozhong Block 11/05 in approximately 75 feet (23 meters) of water.
Project Details: Peng Lai
N. America – US GOM
Marlin Primes Eugene Bit
Jan 26, 2012 – Marlin Energy is preparing to spud the A-2DST01 well, a sidetrack of the existing A-2 well, targeting reserves in the Tex X2 sandstones. The operator is using the Ocean Columbia (250′ ILC) jackup to drill the well at the Eugene Island Field in the GOM. Two sidetrack wells are planned to access new reserves, said partner Leni. Potential pay zones have been identified in the Tex-X2 and X3 reservoirs, and if completed successfully, will lead to an immediate increase in production. The A#2 sidetrack is targeting a downthrown fault block which Marlin considers to have good seismic amplitude. The fault block has an estimated mean recoverable reserve of 0.5 million barrels of oil within the primary, Tex-X2, target level at a depth of approximately 13,000 feet (396 meters) subsea. The slightly deeper Tex-X3 reservoir will also be tested by the well.
Pyrenees Slated for Production in 1Q12
Jan 24, 2012 – The Pyrenees field is in its final stages of flowline and umbilical installation. Liquids-rich gas and condensate production is expected by February 2012 at a gross rate of 60 MMcf/d. Pyrenees is located on Garden Banks 293 in 2,100 feet (640 meters) of water.
Project Details: Pyrenees Discovery
Stone Acquires Stake in Wideberth Development in GOM
Jan 24, 2012 – Stone Energy has acquired a 25 percent non-operated working interest in the deepwater Wideberth development project. The company says that first production from this gas satellite tie-back is expected in 2Q12. Wideberth is located in 3,700 feet (1,132 meters) of water on Green Canyon Block 490.
Project Details: Wideberth
Shell to Appraise Vito in GOM
Jan 20, 2012 – Shell is on location at Mississippi Canyon Block 940 to drill the No. 2 appraisal well on the Vito prospect. The operator is using the Noble Danny Adkins (UDW semisub) to drill the well. Drilling should take about 145 days. The discovery is located in 4,206 feet (1,282 meters) of water.
Project Details: Vito
Chevron Hands Technip Wheatstone Contract
Jan 26, 2012 – Technip Oceania, an Australian subsidiary of France’s Technip Group, has received a contract by Daewoo Shipbuilding and Marine Engineering for the detailed design of Chevron’s Wheatstone offshore gas-processing platform. The offshore portion of the project compromises the development of gas fields in the WA-17-R and WA-253-P petroleum titles located on the northwest shelf offshore Western Australia in water depths of 230 to 655 feet (70 to 200 meters). Subsea gas gathering systems will transport production to the processing platform where the gas and condensate will be treated. It will then export to the onshore gas plant at Ashburton North. Work is scheduled for completion in the second half of 2012. The Chevron-operated Wheatstone project compromises the Wheatstone and Iago gas fields, located in water depths between 330 and 850 feet (100 to 260 meters).
Project Details: Wheatstone
McDermott Makes Big Splash with Ichthys Surf Contract
Jan 25, 2012 – Inpex has granted McDermott International a letter of award for the Ichthys gas/condensate field offshore Australia. The surf contract, with a value of $2 billion, is the largest subsea contract McDermott has received to-date. This project includes engineering, procurement, construction, installation and pre-commissioning of production flowline systems, a MEG injection system, plus start-up condensate transfer and fuel gas transfer flowline systems, control systems, as well as other associated SURF elements in water depths of up to 902 feet (275 meters). McDermott will also install mooring systems for the FPSO and central processing facility, as well as, installation engineering for future flowlines, risers and umbilicals. Engineering work has commenced with fabrication slated for 2013. Gas from the Ichthys field, in the Browse Basin approximately 124 miles (200 kilometers) offshore 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-long (889-kilometer-long) subsea pipeline.
Project Details: Ichthys
ConocoPhillips to Drill Boreas in February
Jan 24, 2012 – ConocoPhillips is gearing up to commence a drilling program in the Browse Basin Australia. The first well, Boreas-1 in WA-315-P, is located 2.7 miles (4.2 kilometers) east of the Poseidon discovery. The well will be drilled in a crestal position on a previously untested fault block with significant gas potential. ConocoPhillips is funding 80 percent of Boreas-1 to fulfill its farm-in commitments. The operator will use the Transocean Legend (mid-water semisub) to drill the well in February 2012.
MEO to Acquire 3D Data over Permit WA-454-P
Jan 24, 2012 – MEO Australia has performed a technical evaluation of the Marina-1 gas and liquids discovery in permit WA-454-P in the Bonaparte Gulf. MEO says that the evaluation has provided sufficient encouragement to warrant an early investment in 3D seismic, as well as information on the nearby Breakwater prospect. Design of and tendering for the Floyd 3D seismic survey targeting Marina, Breakwater and two other leads were completed during the quarter. The contract for acquisition of the Floyd 3D seismic survey was awarded in early January. Acquisition is expected to commence in February and to be completed in March.
Eni to Drill Heron Appraisal Well 3Q12
Jan 24, 2012 – Eni will use the jackup ESNCO 109 (350′ ILC) to drill the Heron-3 appraisal well. The vessel is expected to arrive late in second quarter 2012 with drilling to occur during the third quarter. Heron is located in NT/P68 permit in the Bonaparte Basin offshore Australia.
Project Details: Heron
MEO Commences 3D Seismic Survey in AC/P 50 and AC/P 51
Jan 20, 2012 – MEO Australia Limited has commenced acquisition of a 125,282 acre (507 square kilometer) Zeppelin 3D seismic survey in AC/P 50 and AC/P 51 in the Ashmore Cartier region of the Timor Sea. The survey is scheduled to take about 23 days to record. The permits are in permit year three of the primary exploration term. The Zeppelin 3D seismic acquisition will fulfill the current year work obligation subject to receipt of regulatory approvals for a work program variation for AC/P51.
Statoil Acquires Acreage Offshore Greenland
Jan 23, 2012 – Statoil has acquired a 30.625 percent working interest at the Pitu license in Baffin Bay. The license was awarded to Cairn Energy during the first Baffin Bay licensing round in December 2010. Cairn will continue as operator and will retain a 56.875 percent working interest while partner Nunaoil will retain its carried interest of 12.5 percent. The work program includes the interpretation of recently acquired seismic data. The partnership will evaluate the seismic data prior to making a decision on drilling an exploration well. Cairn will retain operatorship at this stage, while Statoil will operate any future development.
N. America – Mexico
Pemex Confirms Veracruz Hydrocarbon Find
Jan 24, 2012 – Pemex says exploratory well Puskon-1 has proved the existence of an active petroleum system off the coast of Tuxpan, Verazruz, recording a series of hydrocarbon demonstrations. The well, drilled in a water depth of 2,122 feet (647 meters), was designed to evaluate the potential of a possible formation of the Mesozoic, which extends over an area of about 4.9 million acres (20,000 square kilometers). Pemex says the well was set to reach a total depth of 26,657 feet (8,125 meters) but confirmed the presence of wet gas at 23,622 feet (7,200 meters).Recorded temperatures and pressures were higher than predicted at 25,039 feet (7,632 meters). It also updated the geological-geophysical interpretations in order to propose a new future exploration location to assess the potential of this oil objective.
Africa – Other
Afren Plans to Spud Orpheus Prospect in 2012
Jan 24, 2012 – Afren plans to drill the Orpheus prospect in 2012 from an offshore location, and is in the process of securing a jackup drilling rig capable of undertaking this work. During Q4 2011 over 559 miles (900 kilometers) of deepwater 2D seismic was acquired, which is currently being processed. Final results are expected at the end of the 1Q 2012. The Orpheus prospect is situated in the Tanga block mainly offshore northeast Tanzania in coastal to shallow marine waters.
Project Details: Orpheus
Anadarko to Conduct Extensive Testing Program at Barquentine
Jan 20, 2012 – Anadarko is preparing to spud the Barquentine-3 well offshore Mozambique. The Deepwater Millennium (UDW drillship) is currently on location where it will commence an “extensive” testing program, reported Rigzone’s RigLogix Database. The operator plans to install observation gauges and conduct several flow tests. The discovery lies offshore Area 1 of Mozambique’s Rovuma Basin.
Project Details: Barquentine
Africa – West
Afren Plans to Drill Additional Development Well at Okoro
Jan 26, 2012 – Production at the Okoro field has averaged at 15,800 bopd on a gross basis during the period, reported Afren. In the first quarter of 2011, two infill wells were brought onstream, and debottlenecking work was also undertaken in order to increase the production handling capacity of the Okoro FPSO. Afren expects to drill a development well from the existing unmanned wellhead platform at the Okoro field. The Okoro field is located in OML 112 in shallow water offshore Nigeria.
Afren Mulling Okwok Development Plans
Jan 26, 2012 – Afren completed an Ocean Bottom Cable 3D seismic survey over the whole Ebok/Okwok/OML 115 area in 3Q11. The operator is currently processing the new data, which is slated for completion by 2Q12. One of the primary purposes of the new data is to assist in development planning for the Okwok field, and to pinpoint an additional appraisal well that the consortium will drill in the second half of the year, ahead of formal submission of a FDP to the Nigerian authorities. Afren is leaning towards a development plan that incorporates a separate dedicated production processing platform tied-back to the existing Ebok FSO, located about 8 miles (13 kilometers) to the west. The Okwok field is situated on OML Block 67 in 131 feet (40 meters) of water offshore Nigeria.
Project Details: Greater Ebok-Okwok Complex
Oriental Ramps Up Ebok Production
Jan 26, 2012 – Oriental Oil reported that initial phases of the Ebok development have been completed, following the commissioning and ramping of all 14 production wells. Reservoir performance and well deliverability recorded at the field to date are in-line with prognosis, with production processing and regular crude oil offtake operations running smoothly. The Transocean High Island VII (250′ ILC) jackup remains on location at the west fault block area of the field. The consortium plans to drill up to four horizontal production wells from the west fault block location targeting oil-bearing reservoir zones that were not drilled during the initial phases of field development work. The field partners also plan to drill an exploratory well on the Ebok north fault block during the first half of the year. Ebok is located on Block OML 67 offshore Nigeria in a water depth of 135 feet (41 meters).
Project Details: Greater Ebok-Okwok Complex
CAMAC Energy Enters Gambia
Jan 23, 2012 – CAMAC Energy has entered into an agreement with the Gambian Ministry of Petroleum on the provisional award of two offshore exploration blocks, A2 and A5, in water depths ranging in 1,969 to 3,281 feet (600 to 1,000 meters). CAMAC Energy will operate the blocks with an 85 percent interest, which cover a total surface area of 658,783 acres (2,666 square kilometers). Gambia National Petroleum Company will be carried at 15 percent through first oil. The two exploration blocks are located in the highly prospective West African Transform Margin, home to several recent major discoveries in Ghana (Jubilee, Odum) and Sierra Leone (Venus, Mercury). Additionally, in 1979 Chevron drilled the Jammah-1 well on the basis of sparse 2D data in Block A2. The well had gas shows, thereby establishing the presence of hydrocarbons in the area. Extensive 3D seismic shot on the two Gambian blocks A1 and A4, immediately west of the blocks A2 and A5, has revealed a number of material prospects and leads according to the operator African Petroleum Corporation Limited. One of the identified prospects, Alhamdulilah, has potential mean unrisked resources of approximately 500 million barrels.
Hyperdynamics Suspends Sabu-1
Jan 23, 2012 – After encountering equipment problems, Hyperdynamics has suspended drilling operations on the Sabu-1 exploratory well offshore Republic of Guinea. Repairs will be made and the delay is estimated to take about a week. The well reached a total subsea depth of 7,297 feet (2,224 meters), putting the well near the top of Cretaceous age sediments, and the next string of 13-3/8 inch casing was successfully set. Following retesting of the blowout preventer, the well reached a depth of 7,559 feet (2,304 meters). The operator expects to test prospective upper Cretaceous sandstone reservoirs while it drills the Sabu-1 well to a total subsea depth of about 11,811 feet (3,600 meters).
Project Details: Sabu


Worldwide: Project Field Development News


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.

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.
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

Norway: Skarv Start-Up Put Off for 1Q 2012


Oil major BP said it had delayed the start-up of production from its Skarv oil and gas field off Norway until late in the first quarter of 2012, scrapping a previous timetable for late in the fourth quarter of this year.

Originally the field had been due to enter production in August.

“The slippage is due to delays in receiving the vessel, problems with the riser pull-in (process) and the weather conditions,” BP spokesman Jan Erik Geirmo told Reuters on Wednesday.

BP is the operator of the field and has a stake of 24 percent, while the other licensees include Statoil (36 percent), PGNiG of Poland (12 percent) and Germany’s E.ON Rurhgas (28 percent).

On Tuesday PGNiG cut its forecast for next year’s production from Skarv by 40 percent to 0.24 billion cubic metres and said the field’s launch would be delayed until 2012.

Poland’s gas monopoly also slashed expected oil production from the field to 250,000 tonnes in 2012.

Geirmo declined to say how the delayed start-up would affect production estimates.

Shares in Statoil were down 1.79 percent at 137.2 crowns at 1126 GMT, while the Oslo benchmark index was up 0.54 percent.

Carnegie analyst John Olaisen said the fall was due to the delay at the Skarv field, adding that he thought it would shave 2 percent off Statoil’s planned 2012 output.

Statoil declined to comment on how the delay at Skarv would impact production targets for this year and the next.

“We will present our numbers … with our third-quarter results next Thursday (Oct. 27),” said Statoil spokesman Ola Anders Skauby.

In June Statoil said that a delay in Skarv’s start-up, then pushed back to the fourth quarter of 2011, would reduce 2011 output by some 10,000 barrels of oil equivalent per day (boepd).

The Norwegian firm so far expects its 2011 production to be slightly under 2010′s 1.9 million boepd.

The company has a history of missing its production forecasts.

According to the Norwegian Petroleum Directorate the Skarv field contains 104 million barrels of oil and 42.1 billion cubic metres of gas.

By Walter Gibbs and Joachim Dagenborg (Reuters)


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