Category Archives: Offshore FIeld Development
This week the SubseaIQ team added 4 new projects and updated 13 projects. You can see all the updates made over any time period via the Project Update History search. The latest offshore field development news and activities are listed below for your convenience.
Africa – West
Oct 24, 2013 – Lukoil completed drilling the Savannah-1X wildcat in the Sl-5-11 license offshore Sierra Leone. The well was drilled on schedule by the Eirik Raude (UDW semisub) to a depth of 14,519 feet. Several oil-bearing reservoirs were confirmed and oil samples were taken from Turonian sands. Drilling data will be evaluated through the end of the year to advance the company’s geological understanding of the area.
Project Details: Savannah
Asia – Far East
CNOOC Announces Additional Bohai Bay Discoveries
Oct 24, 2013 – CNOOC announced an oil discovery at its Luda 5-2 North field in Bohai Bay. The Luda 5-2N-2 and Luda 5-2N-4 wells were each drilled to a depth of 3,740 feet and encountered gross pay zones of 390 and 280 feet respectively. Luda 5-2N-2 tested oil at a rate 1,040 barrels per day. Additionally, the company announced the successful appraisal of the Kenli 9-5/9-6 oil field. The Kenli 9-5-2D and 9-6-2 wells were drilled in the southern part of Bohai Bay. Kenli 9-6-2 flowed at a rate of 200 barrels per day.
S. America – Brazil
Petrobras-led Consortium to Develop Pre-Salt Libra Field
Oct 24, 2013 – A group of companies comprised of Petrobras, Shell, Total, CNPC and CNOOC won a 35-year production sharing contract to develop the Libra pre-salt oil field in the Santos Basin offshore Brazil. Libra is located in block BM-S-11 in 6,500 feet of water and is estimated to hold as much at 12 billion barrels of oil. Additional appraisal will be needed to determine the best development scenario and to confirm production rates that are currently estimated at 1.4 MMbopd. Petrobras will serve as the operator with a 40 percent stake on behalf of its partners Shell (20 percent), Total (20 percent), CNPC (10 percent) and CNOOC (10 percent).
Europe – North Sea
Oct 24, 2013 – Drilling results at Eni’s Bonna prospect in the Barents Sea proved to be disappointing. Well 7016/2-1 was drilled by the Scarabeo 8 (UDW semisub) to a depth of 13,205 feet. The well was drilled to investigate the possibility of gas in the Eocene and Paleocene reservoirs of the Sotbakken Group. No reservoir-quality rocks were encountered and the well has been declared dry.
Project Details: Bonna
Asia – SouthEast
Oct 24, 2013 – Neon Energy announced the spud of the Ca Ngu-1 exploration well in Block 120 offshore Vietnam. The objective of the well is to prove the presence of hydrocarbons in Pliocene clastic and Miocene carbonate reservoirs. Block operator ENI secured the Songa Mercur (mid-water semisub) to drill the well in 885 feet of water to a target depth of around 4,900 feet. If successful, the well could de-risk the nearby Rua Bien and Ca Lang prospects. Block 120 partners consist of ENI (50%), Neon Energy (25%) and KrisEnergy (25%).
Project Details: Ca Ngu
Oct 24, 2013 – Subsea tree installation, well clean-up and flow testing of the Galoc-6H development well have successfully been completed at the Otto Energy-operated Galoc field. Galoc-6H flowed at a stable rate of 3,800 bopd on a 56/64-inch choke with a flowing tubing pressure of ~570 psi. These results were constrained by the testing equipment onboard the Ocean Patriot (mid-water semisub). Once tied into production facilities, Otto expects normal production from the well to reach 4,000 to 6,000 bopd. The 5H and 6H wells were drilled as part of the Phase II development plan which aims to increase field production to 12,000 bopd. Phase II production is scheduled to begin in November 2013.
Project Details: Galoc
S. America – Other & Carib.
Oct 25, 2013 – French supermajor Total announced its decision to move forward with the development of the Vega Pleyade gas and condensate field offshore Argentina. The field is located in the Cuenca Marina Austral 1 (CMA-1) concession that Total has operated since 1978. Development consists of installing a new production platform in about 160 feet of water. Three production wells will be drilled from the platform and produced gas will flow through 48 miles of subsea pipeline to a treatment plant at Rio Cullen. In a separate initiative, Total will begin a drilling campaign in 2014 aimed at boosting production from the Carina field and providing additional appraisal in CMA-1. Total owns a 37.5 percent stake in the concession. Its partners include Wintershall (37.5 percent) and Pan American Energy (25 percent).
Project Details: Vega Pleyade
Oct 25, 2013 – Drilling operations are complete at the Eni-operated Evans Shoal North-1 appraisal well. The well, located in the Timor Sea, was drilled by the Ensco 104 (400′ ILC) to a depth of almost 13,000 feet. Results indicate that the Evans Shoal North-1 reservoir is in communication with the reservoir encountered while drilling Evans Shoal-2. Eni conducted a production test and achieved a constrained rate of 30 MMscfd. The operator estimates the Evans Shoal field to contain at least 8 Tcf of in place gas resources and remains committed to establishing a fast-track development in the area. Eni’s partners in the field include Shell (32.5 percent), Petronas (25 percent) and Osaka Gas (10 percent).
Project Details: Evans Shoal
Oct 25, 2013 – ExxonMobil announced the start of production from its Kipper Tuna Turrum (KTT) project in the Bass Strait. Gas is now being produced at the Tuna field and oil is flowing from Turrum to the Marlin B production platform. At $4.3 billion, KTT is the largest domestic oil and gas development on Australia’s eastern seaboard. Production startup from the Kipper field is expected to commence in 2016.
Project Details: Kipper Tuna Turrum (KTT)
This week the SubseaIQ team added 6 new projects and updated 26 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
Oct 2, 2013 – Lundin Petroleum completed a production test on the Permian carbonate reservoir encountered in the previously announced Gohta discovery. During the test, a maximum flowrate of 4,300 bopd was achieved through a 44/64″ choke with a gas/oil ration of 1,040 standard cubic feet per barrel. Flow properties were stable for over 24 hours with pressure build-up lasting 36 hours. Gohta is the first successful flow test of Permian carbonate reservoirs on the Norwegian shelf. Early estimates of Gohta oil and gas resources indicate the possibility of between 105 and 235 MMboe.
Project Details: Gohta
Oct 2, 2013 – Drilling is underway at the Pharos prospect in UK North Sea license P1566. Well 47/5d-6 is being drilled by the Noble Lynda Bossler (250′ ILC) and is targeting an estimated 500 Bcf of natural gas in the Rotliegendes formation. The large prospect covers portions of blocks 47/4d, 47/5d and 47/10c and is thought to contain nearly three times the amount of gas as the 2010 Platypus discovery just over 8 miles away. If successful, it is possible that Pharos and Platypus could be developed as a single project. Partners in the license include Dana Petroleum (35%) as operator, Parkmead (20%), Dyas Exploration (15%), MPX (15%) and Hansa (15%).
Project Details: Pharos
Oct 1, 2013 – Lundin Petroleum’s most recent Johan Sverdrup delineation well encountered an oil column approximately 20 feet thick in excellent quality Upper Jurassic sands in the south western portion of license PL501. Well 16/5-4 was drilled by the Bredford Dolphin (mid-water semisub) to a depth of 6,808 feet. A pressure gauge was installed down hole to monitor pressure development in the reservoir over a period of 2 to 5 years. The rig will now move to the southeastern flank of Johan Sverdrup to drill the 16/3-7 appraisal well.
Project Details: Johan Sverdrup
Oct 1, 2013 – Lundin Petroleum announced the start of exploratory drilling with the spud of well 16/2-20S at the Torvastad prospect just north of the Johan Sverdrup discovery in license PL501. The well is designed to test the northern extension and quality of the Jurassic reservoirs found in Johan Sverdrup. The well will be drilled by the Island Innovator (mid-water semisub) to a depth of 6,807 feet. Lundin, the license operator, expects the rig to be on location for 55 days. Equity holder in PL501 include Lundin (40%), Statoil (40%) and Maersk Oil (20%).
Project Details: Torvastad
Asia – SouthEast
Oct 3, 2013 – SOCO International announced the results of a production test conducted on the TGT-10XST1 well which was recently drilled at the Te Giac Trang field off Vietnam. The well cut through over 800 feet of pay in Oligocene and Miocene reservoirs. Three zones were evaluated during the test which was carried out over one Oligocene and two Miocene sections. Testing achieved a combined average flowrate of 27,600 boepd. The well is one of the most prolific ever drilled off the coast of Vietnam.
Project Details: Te Giac Trang (White Rhinoceros)
Salamander’s Ayutthaya Well P&A’d as Dry Hole
Oct 1, 2013 – Salamander Energy reached total depth at the Ayutthaya well in Block G4/50 in the Gulf of Thailand. The well was drilled to 7,526 feet and encountered excellent quality reservoirs prognosis. Unfortunately, no signs of hydrocarbons were seen while drilling or on wireline logs. The well has been plugged and abandoned.
Africa – Other
Oct 3, 2013 – BG Group’s Pweza discovery appraisal program continues to be successful. The Deepsea Metro I (UDW drillship) drilled the Pweza-3 well to total depth and conducted a 5-day drill stem test (DST) that delivered a maximum flowrate of 57 MMscfd. The results were constrained by testing equipment which shows that Pweza development wells could be capable of flowing at much higher rates. The rig will now relocate to Block 1 to drill the Mzia-3 appraisal.
Project Details: Pweza
Oct 1, 2013 – Noble Energy, operator of Block 12 in the Cyprus Exclusive Economic Zone, carried out a successful production test at the Aphrodite-2 appraisal well. The test was performed onboard the Ensco 5006 (DW semisub) for a duration of 5 days. Delek Group, a junior partner in the well, reported an average flow rate of 32.7 MMscfd with an initial reservoir pressure of 8,961 psi. No appreciable decline in pressure was observed. Well test results were constrained by the testing equipment. Once the well is secured the rig will sail back to Israeli waters to drill the South West Tamar exploration well in the Eran/353 license.
Project Details: Aphrodite
S. America – Brazil
Oct 3, 2013 – Karoon Gas Australia continues to progress engineering and geotechnical studies related to its Kangaroo oil discovery off Brazil. Kangaroo and the undrilled Kangaroo West prospect will be the focus of Karoon’s Phase 2 drilling program in the Santos Basin. The Karoon-2 appraisal well is being planned as a priority to confirm the size of the oil column and to confirm the reservoir properties and continuity up-dip from the discovery well. Kangaroo West-1 will be drilled as the second well in Phase 2 due to its potential size which could be in excess of 150 million barrels and proximity to the main field. Additionally, Karoon contracted Worley Parsons and Intecsea to undertake pre-FEED studies for the development. If the Kangaroo work program yields positive results first oil could be seen as early as 2018.
Project Details: Kangaroo
Asia – South
Oct 2, 2013 – Production at the Sangu gas field has come to an end after several years of steady decline in production rates. Sangu is the only gas field off the coast of Bangladesh. Santos, the operator, made the decision to shutdown the operation as it was only able to produce 2.4 MMcfd which is far below the 15 MMcfd needed to make the project economically viable. As part of the Production Sharing Contract Santos will hand over control of the platform, subsea pipeline and onshore processing plant to state-run Bangladesh Oil, Gas and Mineral Corporation, or Petrobangla.
Project Details: Sangu
S. America – Other & Carib.
Oct 3, 2013 – Total announced the receipt of regulatory approval for a transaction that will see the company transfer its 30% working interest in Block 2(c) to The National Gas Company of Trinidad & Tobago (NGC) for $437 million. Block 2(c) contains the producing Angostura, Aripo, Canteen and Kairi fields that make up the Greater Angostura Area. NGC’s share of production from the fields will amount to approximately 15,000 beod. Total’s divestment of these assets is in line with the company’s strategy of freeing up capital to focus on areas that possess higher growth potential.
Project Details: Greater Angostura
Oct 1, 2013 – Development drilling is underway at the Albacora field in Block Z-1 off the coast of Peru. BPZ Energy announced the spud of the A-18D well from the Albacora platform. It is expected to take twelve weeks to reach the proposed total depth of 12,000 feet. Development drilling at the Corvina field commenced in July with the CX15-1D well. Results from the well are expected in October. BPZ, the field operator, and its partner Pacific Rubiales plan to drill at least 2 wells at Albacora and 3 well at Corvina as part of the development program.
Project Details: Albacora
Stone Energy Corporation provided an update on the deep water Taggart prospect, including the exploratory well drilled at Mississippi Canyon 816. Drilling operations have been completed and the rig is being released.
The well has been logged, and pressure readings, cores and fluid samples have been taken in the Pliocene and Upper Miocene section sands. The data indicates a discovery with approximately 90 feet of net oil and gas condensate pay in two sands. The partners plan to further analyze the data from this well and develop a plan which is expected to include a sub-sea tie back to an existing facility. Stone holds approximately 23% working interest in the project, and LLOG Exploration Offshore, L.L.C. is the operator.
A discovery was also made on the Taildancer prospect at Ship Shoal 113, with the well encountering 130 feet of net oil and gas pay. Production from this discovery is projected to be on line in the fourth quarter of 2013. Stone is the operator with a 100% working interest.
The rig for the deep water San Marcos prospect at Mississippi Canyon 983 is on location and has begun drilling. Stone holds a 25% working interest in the prospect which is operated by Apache Deepwater LLC.
Stone also provided updated production guidance for the third quarter of 2013, increasing from 42-45 Mboe per day (252-270 MMcfe per day) to 46-49 Mboe per day (276-294 MMcfe per day). The full year guidance has also been increased from 41-44 Mboe per day (246-264 MMcfe per day) to 43.5-45.0 Mboe per day (261-270 MMcfe per day). The increase was due to higher projected Appalachian volumes, incremental volumes from the La Cantera field and a more active workover/recompletion GOM shelf program. The guidance still incorporates some projected hurricane shut-in time as well as reduced fourth quarter volumes in Appalachia due to cold weather pipeline restrictions.
Additionally, Stone’s Board of Directors has authorized an increase to the 2013 capital expenditure budget from $650 million to $710 million, which excludes major acquisitions and capitalized SG&A and interest. Most of the capital expenditure budget increase is expected to be in the GOM deep water, with a minor increase in the Appalachia area. The final capital expenditure amount and the allocation of capital across the various areas is subject to change based on several factors including permitting times, rig availability, non-operator decisions, farm-in opportunities and commodity pricing.
|This week the SubseaIQ team added 13 new projects and updated 30 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.|
Shell’s massive Olympus tension leg platform (TLP) set sail from Ingleside, Texas on 14th July, for a 425 mile trek to its final home on the Mars Field in the Gulf of Mexico.
For 10 days, tugboats will transport the over 120,000 ton platform to the location where work will begin to secure the platform in place. The Olympus TLP will be moored to the seafloor by tendons grouped at each of the structure’s corners and will float in approximately 3000 feet of water.
The Olympus TLP is Shell’s sixth and largest tension leg platform and will provide process infrastructure for two of Shell’s deep water discoveries, West Boreas and South Deimos. The project also includes pipelines that will be routed through West Delta 143C, the recently installed shallow water platform.
The Olympus TLP is expected to start production in 2014, producing at a rate of 100k boe.
This week the SubseaIQ team added 5 new projects and updated 23 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.
Asia – SouthEast
Jul 12, 2013 – Premiere Oil announced that on June 21 a planned 4-week shutdown of the Anoa field gas processing facility commenced to allow the completion of the Phase 4 compression project. The project was implemented to add additional gas processing capacity to handle the decline of oil production and the increase of associated gas production. First gas is expected near the end of July with final commissioning to be complete by September. Phase 4 will allow the commercialization of roughly 200 Bcf of undeveloped proven reserves. The Anoa field is located off Indonesia in Natuna Sea Block A. Premier (28.667%) operates the field on behalf of its partners KUFPEC (33.33%), Hess (23%) and Petronas (15%).
Project Details: Anoa
Jul 12, 2013 – KrisEnergy, operator of the Kutai PSC offshore Indonesia, announced the completion of drilling operations at the Tayum-1 exploration well. Shelf Drilling’s Randolph Yost (300′ ILC) drilled the well directionally to a measured depth of 11,095 feet (8,410 feet total vertical depth). Almost 50 feet of net gas pay was encountered over multiple sandstone intervals. The well has been plugged and abandoned as a gas discovery.
Project Details: Tayum
Jul 11, 2013 – Nido Petorleum secured a 12-month extension from the Philippines Department of Energy relating to Sub-Phase 6 for Service Contract (SC) 54A. Sub-Phase 6 now has an effective end date of Aug 4, 2014 and Sub-Phase 7 will commence Aug 5, 2014 and last for 12 months. The extension allows Nido and its partners additional time to complete engineering and development studies prior to making the decision on whether or not to enter Sub-Phase 7. Lawaan is the leading drillable prospect in SC54A with oil-in-place estimates of 34.7 million barrels.
Project Details: Lawaan
Africa – West
Jul 11, 2013 – Ophir Energy’s Starfish-1 well has been drilled to 14,370-feet total depth (TD) by the Stena DrillMax (UDW drillship) in the Accra PSC offshore Ghana. A wireline logging program was carried out in the well that confirmed over 750 feet of gross water-bearing sandstone in the primary target. The secondary target was determined to be comprised of poorly developed sands that were also water-bearing. Evaluation of the logging data will continue in an effort to help the PSC partners decide by the Sept. 23-deadline on whether or not to proceed with the Phase 2 work program.
Project Details: Starfish
Jul 11, 2013 – The partners in Namibian license PEL0010 selected the new-build Rowan Renaissance (UDW drillship) to drill the Welwitschia-1 exploration well. Rig delivery is expected to take place in December 2013, at which point the drillship will sail directly to Namibia to spud the well in mid-February 2014. Detailed well planning is underway and a site has been selected that will allow the well to test the primary and secondary targets in Maastrichtian and Aptian-Albian reservoirs. Procurement of long-lead items is underway with deliveries to begin by the end of the year. License partners include Repsol (44%) as operator, Tower Resources (30%) and Arcadia (26%).
Project Details: Welwitschia
Europe – North Sea
Jul 12, 2013 – Bridge Energy, a partner in UK license P1763, announced the Blackford Dolphin (DW semisub) has been contracted by operator-MPX North Sea to test the Aragon prospect with an estimated spud date in 1Q 2014. Aragon is located near the Beryl field and the well will be target sands in the Upper Jurassic Heather formation. Drilling the exploration well will fulfill a work commitment that needs to be completed before 1Q 2015.
Project Details: Aragon
Jul 12, 2013 – Premier Oil and KUFPEC Norway AS have entered into an agreement to acquire BG Group’s entire 40% interest in license PL407 on the Norwegian continental shelf. If approved by regulatory authorities, the revised license ownership will consist of Premier (50%) as operator, KUFPEC (30%) and Tullow (20%). PL407 contains the Bream discovery which has been estimated to contain around 50 MMboe. Development of the field is expected to be sanctioned at some point in 2014.
Project Details: Bream
Jul 12, 2013 – Lundin Petroleum announced the successful completion of its latest Johan Sverdrup appraisal well. Well 16/3-6 was drilled by the Bredford Dolphin (mid-water semisub) to a depth of 6,643. A 37-foot oil column was discovered in good quality Upper Jurassic sandstone. The rig will now mobilize to license PL544 to drill well 16/4-7 on Lundin’s Biotitt prospect.
Project Details: Johan Sverdrup
Jul 12, 2013 – Cairn Energy’s 38% farm-in as operator of Frontier Exploration Licenses (FEL 2/04) and 4/08 has been approved by Ireland’s Minister of State at the Department of Communications, Energy and Natural Resources (DCENR). License FEL 2/04 contains the Burren and Spanish Point discoveries and FEL 4/08 holds the Cama oil prospect. Cairn has contracted the Blackford Dolphin (DW semisub) to drill an appraisal well at Spanish Point in 2Q 2014. In addition to the two FELs, Cairn also secured operatorship of a licensing option in the Porcupine Basin covering 1,062 square miles.
Project Details: Spanish Point
Jul 11, 2013 – The Norwegian Petroleum Directorate (NPD) granted Statoil a permit to drill an exploration well at its Iskrystall prospect in license PL608. Well 7219/8-2 will be drilled by the West Hercules (UDW semisub) in 1,128 feet of water. The well will test a similar early-middle Jurassic play that was proven by the Skrugard and Havis discoveries but is thought to lie at a much greater depth at Iskrystall.
Project Details: Iskrystall
Jul 11, 2013 – Lundin Petroleum announced the spud of well 16/2-18S in Norwegian license PL265. The well is being drilled by the Ocean Vanguard (mid-water semisub) to test the presence of quality Jurassic reservoir and the quality of fractured and weathered basement rock. Additionally, the well will serve to delineate the northeast extension of the Johan Sverdrup discovery. The rig is expected to be on location for 40 days while drilling to the proposed total depth of 6,463 feet.
Project Details: Johan Sverdrup
Jul 11, 2013 – A wireline logging program being carried out in Apache’s Bianchi-1 well off Western Australia was interrupted to conduct unspecified repairs to the Ocean America (DW semisub). Enough data was acquired prior to the shut-down, confirming a gas discovery in the upper sands of an interval that LWD data indicated to be gas-bearing. The Bianchi joint venture has agreed to drill an additional 100 feet to a total depth (TD) of 17,789 feet. Upon reaching TD, the wireline program will recommence to complete the evaluation of the well.
Project Details: Bianchi
Jul 11, 2013 – IPB Petroleum and CalEnergy were granted a 12-month suspension and extension to years 2 and 3 regarding the work program for permit WA-424-P off Western Australia. A tight rig market prompted the joint venture partners to seek the extension in order to have more time to source a suitable rig to drill an exploration well on the Pryderi prospect. The extra time also allows for the submission of needed revisions to the Pryderi Environmental Plan and Oil Spill Contingency Plan. Submission of the revisions is expected to take place mid-July 2013. Assuming the revisions are accepted and all regulatory approvals are granted, IPB expects to be ready to spud Pyderi-1 in 4Q 2013.
Project Details: Pryderi
Shell announces a successful exploratory well at Vicksburg in the deepwater Gulf of Mexico. The well is located 75 miles (120 kilometers) offshore in the De Soto Canyon Block 393 in 7,446 feet (2,269 meters) of water. It was drilled to a total depth of 26,385 feet (8,042 meters) and encountered more than 500 feet (152 meters) of net oil pay.
In total, the Vicksburg “A” discovery is estimated to hold potentially recoverable resources of more than 100 million barrels of oil equivalent (mmboe). It adds to the more than 500 mmboe of potentially recoverable resources that have already been discovered and appraised at the nearby Appomattox discovery. Vicksburg “A” is a separate accumulation from both Appomattox and the 2007 Vicksburg “B” discovery.
“The results of the Vicksburg well strengthen our existing deepwater Gulf of Mexico exploration portfolio and should contribute to the nearby Appomattox discovery,” said Mark Shuster, Executive Vice President Shell Upstream Americas Exploration.
Shell (the operator with a 75% interest) and Nexen, a wholly-owned subsidiary of CNOOC Limited, (25% interest), are following up the Vicksburg “A” well with a sidetrack well to test the Corinth prospect, a separate fault block from the Vicksburg discovery. Further exploration drilling targeting tie-backs to Appomattox will follow.
Press Release, July 03, 2013; Image: Shell
This week the SubseaIQ team added 5 new projects and updated 28 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
Jun 14, 2013 – Total E&P has secured the services of EPC Offshore to support the development of the Edradour gas and condensate discovery in block 206/4 on the UK continental shelf. EPC will provide project management services for the development as part of a 6-month contract worth more than $400,000. Edradour was discovered in 2010 and will be tiebacked to the West of Shetland Laggan-Tormore development project. Total operates Edradour with 75% interest while it partner, DONG, maintains the remaining 25% interest. The partners expect the discovery to begin producing in 2016.
Project Details: Laggan-Tormore
Jun 13, 2013 – AMEC has been contracted by Xcite Energy to provide engineering services to support development of the Bentley field in the UK North Sea. Both companies have also entered into a Memorandum of Understanding (MOU) to develop a wider service agreement for the field relating to development scope and ongoing field operations. The MOU includes project and program management and controls, engineering and design through the FEED stage and beyond, fabrication management, sub-contractor management, hook-up and commissioning, operations and maintenance planning and duty holder services.
Project Details: Bentley
Jun 13, 2013 – Ithaca Energy signed a $200 million managed services contract with Wood Group PSN (WGPSN). The life-of-field contract is a continuation of a contract that WGPSN was awarded in 2008. Terms dictate that WGPSN will operate and manage the Beatrice Alpha and Bravo platforms and the Nigg onshore terminal until the end of their operational life. Production started at Beatrice in 1981 with an estimated 30-year lifespan. Several asset life extension programs have been carried out that have greatly increased the life of the field.
Project Details: Greater Beatrice Area
Jun 13, 2013 – Statoil announced the results of two appraisal wells that were drilled by the Ocean Vanguard (mid-water semisub) in the western margin of the Johan Sverdrup field. Well 16/2-17S reached a depth of 6,617 feet and penetrated 270-feet of gross oil pay in Jurassic sandstones. A production test was conducted and yielded almost 6,000 bopd with exceptional flow properties in the upper part of the reservoir. Well 16/2-17B was drilled as a sidetrack to the 17S well. Its target was the Cliffhanger South prospect but no hydrocarbons were encountered and the well has been classified as a dry hole.
Project Details: Johan Sverdrup
Jun 11, 2013 – Bridge Energy, minority partner in Norwegian license PL511, indicated that reservoir quality sandstones have been encountered by the Transocean Arctic (mid-water semisub) while drilling exploration well 6406/6-3 on the Mjosa prospect. Initial results indicate the presence of a sub-commercial volume of gas within the reservoir. Data is still being acquired and further interpretation will be needed to determine what potential exists within the prospect. The current plan is to plug and abandon the well upon reaching total depth.
Project Details: Mjosa
Africa – Other
Jun 11, 2013 – India’s ONGC Videsh (OVL) and Oil India Ltd (OIL) confirmed that they are in advanced negotiations to buy Videocon Industries’ 10% stake in Area 1 offshore Mozambique for $2.47 billion. Several high-profile discoveries have occurred in the area since 2009 and the potential exists for Area 1 to be one of the world’s largest LNG producing hubs by 2018. Recoverable gas reserves for Area 1 are estimated between 35 and 65 Trillion cubic feet (Tcf). If approved, the acquisition will be executed through a 60/40 joint venture between OVL and OIL.
Project Details: Atum
Jun 13, 2013 – ConocoPhillips and Karoon Gas Australia, partners in WA-398-P, have been forced to sidetrack an exploration well being drilled on the Proteus prospect being drilled by the Transocean Legend (mid-water semisub) off Western Australia. Proteus-1ST1 was successfully kicked-off and drilled to 14,740 feet where a well control event forced the partners to shut-in the well. Drilling will continue once the well control issues are remedied.
Project Details: Proteus
N. America – US GOM
Jun 14, 2013 – Noble Energy announced results from the second appraisal well drilled on the Gunflint discovery in Mississippi Canyon block 948 in the US Gulf of Mexico. The well was drilled by the Ensco 8501 (DW semisub) to a depth of 32,800 feet. A net pay of 109 feet was encountered within the primary reservoir targets. Logging results confirmed an estimated gross resource range of 65 to 90 MMboe in the main target. An adjacent three-way structure is a candidate for future exploration. Noble and its partners are likely to develop the discovery as a subsea tieback with project sanction expected later 2013.
Project Details: Gunflint (Freedom)
Jun 13, 2013 – 2H Offshore, a subsidiary of Acteon, was awarded a contract by ExxonMobil regarding the first development phase of the Julia project in the Walker Ridge area of the US Gulf of Mexico. Julia will be a subsea development tied back to the Jack/St. Malo floating production unit. Under the contract, 2H will conduct a detailed design study of two 10-inch steel catenary production risers. ExxonMobil and Statoil made the decision to proceed with the chosen development concept in May 2013. Production start-up is planned for 2016.
Project Details: Jack/St. Malo
Jun 11, 2013 – Anadarko continues to shop for its Heidelberg development in the US Gulf of Mexico with a recent contract award to Subsea 7. Work scope includes the engineering, fabrication and installation of risers, pipelines and flowlines. The installation work will be performed in over 5,200 feet of water. Project management and engineering will begin immediately with offshore activities to follow near the end of 2014.
Project Details: Heidelberg
Asia – SouthEast
Jun 14, 2013 – Nido Petroleum, operator of Service Contract 58, secured a 6-month extension to its Election to Drill Date from its joint venture partner PNOC Exploration. The extension gives Nido until January 11, 2014 to make the decision to drill one of the prospects identified in the area. Located adjacent to the Malampaya gas field, SC58 covers almost 3,335,922 acres. Water depth exceeds 3,280 feet over most of the block. Promising prospects located in the license include Balyena, Butanding and Dorado.
Project Details: Balyena
Jun 14, 2013 – The Stena Clyde (mid-water semisub) has spud the second well in its current drilling program in the Gulf of Papua off Papua New Guinea. Hagana-1 is being drilled in PPL 244 in almost 350 feet of water. The rig is expected to be on location for roughly 40 days as it tests the Pleistocene sandstone structure. Oil Search (40%) operates the license with support from its partners Total (40%) and Nippon Oil (20%). Hagana has been estimated to contain up to 1.3 Tcf of mean, unrisked, prospective gas resources.
Project Details: Hagana
Jun 13, 2013 – Otto Energy received a 6-month extension from the Philippines Department of Energy for Exploration Sub-Phase 3 of Service Contract (SC) 69. Sub-Phase 3, which began February 7, 2011, now has an effective expiration date of November 7, 2013. Three potential drilling targets, Lampos, Lampos South and Managau East, were identified with 3D seismic that was acquired in 2011. Otto will use the extension to complete outstanding technical work, begin well planning and start a farm-down process.
Project Details: Lampos