Category Archives: P & A
InterMoor, an Acteon company, has successfully completed a contract with Cross Group, Inc. that included the provision of heave-compensation services for the installation of a Cross 7.0 workover riser package (WRP).
An InterMoor compensated anchor-handler subsea installation method (CASIM) unit played a key role in deploying and recovering the WRP.
“The CASIM system enabled us to provide effective heave compensation and to recover the delicate WRP on a vessel without an active heave-compensated crane or stern roller,” said InterMoor vice president of business development David Cobb. “That was the only way to achieve the WRP installation from this vessel. The success of this project underlines the value of the CASIM system as a cost- and time-effective solution, and explains why more and more subsea contractors and operators are choosing it to facilitate the installation of workover packages.”
Each standard CASIM unit has a maximum stroke of 3 meters and can accommodate loads up to 50 tons.
The heave compensation operation was in water depths of about 140 meters and used Cal Dive’s Uncle John DP saturation diving vessel to install the 29-ton WRP. The project took place at East Cameron well 378#3, offshore Louisiana, USA. The Cross Group is conducting a plugging and abandonment (P&A) program in the field for EPL Oil & Gas, Inc.
This project demonstrates how InterMoor can provide cost-effective solutions for the installation of subsea workover equipment using vessels of opportunity. Operators trust InterMoor to be part of their P&A campaigns and to help them meet BOEMRE NTL No. 2010-G05 requirements for timely decommissioning of idle infrastructure on active leases.
Claxton, an Acteon company, which specializes in engineering and services for jack up environments, has presented its SABRE subsea abrasive cutting system.
The Claxton SABRE abrasive cutting system is capable of simultaneously severing all the casings in a well, regardless of casing loading, eccentricity or contents.
SABRE has proven an invaluable tool and has seen successful use on some of the most significant abandonment campaigns. SABRE’s abrasive jet exits the tool at transonic speeds – making light work of even composite materials such as cemented casings.
Using a jet of naturally occurring cutting components (garnet, water and air), SABRE has a low environmental impact. The system can be deployed from a vessel or platform, allowing simultaneous abrasive cutting of multiple well casings without impacting adjacent infrastructure.
Offshore Installation Services (OIS), an Acteon company, has successfully completed its 16th rigless suspended-well abandonment campaign involving multiple operators in the Southern North Sea. The multi-operator model for programmes of this kind can deliver significant customer benefits in terms of cost-effectiveness. A total of nine mudline wells in categories 1, 2.1, 2.2 and 2.3 were abandoned during the operation including four on behalf of GDF SUEZ E&P UK Ltd. and two for RWE Dea.
The scope of work for OIS, part of Acteon’s activity and resource management business, included the initial approval processes; formulating the contracting strategy; developing detailed procedures; procurement; appointing specialist service providers; overall logistics; and recycling and disposing of the recovered wellheads.
OIS conducted the two-phase abandonment operation from a chartered DP2-class anchor-handling tug supply vessel (AHTS). During phase one, a proprietary twin low-pressure packer tool from Acteon sister company Claxton Engineering Services Ltd. was deployed through the vessel’s moon pool to set cement plugs across all the casing annuli. The second phase involved abrasive severance of the wells using Claxton Engineering’s SABRE cutting tool.
“We have a strong track record in providing commercially efficient decommissioning solutions which are particularly important for non-revenue-generating assets,” said OIS vice president of commercial and business development Tom Selwood. “Multi-operator campaigns such as this, enable operators to share the associated costs which, when combined with the rigless nature of our offering, makes this the most cost-effective way to comply with UK oil and gas decommissioning legislation.”
Max Proctor, GDF SUEZ E&P UK drilling manager, added, “We are committed to fulfilling our responsibility to the environment as an operator and are leading the way in the North Sea with the decommissioning of redundant wells. We started this campaign immediately after the request came from DECC for operators to fully abandon suspended wells by reviewing the history of the wells and confirming the status of each with an independent well examiner. OIS is a valued partner of GDF SUEZ and the success of this project is testament to the team’s strong technical skills and experience.”
Since 1996, the OIS team has successfully completed more than 100 well decommissioning projects without a single lost-time incident.
This week the SubseaIQ team added 3 new projects and updated 9 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 – Far East
CNOOC Bolsters South China Sea Production
Jan 3, 2013 – Production has started at CNOOC’s 100% owned Liuhua 4-1 field in the South China Sea. Liuhua 4-1 is a subsea development consisting of one production manifold and eight production wells. They are produced through the Nanhai Tiao Zhan FPS and then pumped to the Nanhai Sheng Li FPSO. Peak production is expected to be reached later this year. In addition, the company completed an adjustment project on the Panyu 4-2 and 5-1 oilfields. The objective of the project was to achieve more efficient production from the two fields through shared facilities.
Europe – North Sea
North Sea Energy Provides Badger Update
Jan 3, 2013 – North Sea Energy’s operating committee recently held a meeting to discuss the path forward regarding the Premier Oil-operated Badger prospect in the UK North Sea. Badger is a structural/stratigraphic trap with an objective in lower Cretaceous Coracle and Punt sandstones. Further delineation is required and critical risk elements need to be mitigated before a drilling decision can be made. The company hopes to be in a position to make that decision by the end of 3Q 2013.
Jan 3, 2013 – Det norske, on behalf of the partners in Production License 001B, submitted to the Norwegian Ministry of Petroleum and Energy the Plan for Development and Operation of the Ivar Aasen field. If approved, first oil could be seen in 4Q 2016. Information gained during appraisal drilling indicates that the field contains 150 mmboe and will produce at a steady rate of 23,000 boepd. The development will also include the Hanz and West Cable discoveries. Hanz will be utilized by a subsea installation tied back to a production platform servicing Ivar Aasen and West Cable.
Project Details: Ivar Aasen
Jan 3, 2013 – BP announced the start of production systems at the Skarv field on December 31, 2012. Over its life, Skarv is expected to produce over 100 million barrels of oil and condensate and over 1.5 trillion cubic feet of rich gas. Water depth at the location is almost 1,500 feet. Development facilities include a new harsh environment FPSO, five subsea templates and a 50 mile export pipeline. Production rates will gradually increase over the year to an expected maximum daily rate of 165,000 boed.
Project Details: Skarv/Idun
S. America – Other & Carib.
Priodontes Well Spuds Off French Guiana
Jan 3, 2013 – Shell, as operator of the Guyane Maritime Permit (French Guiana), spudded an exploration well at the Priodontes prospect on December 29, 2012. The well is being drilled by the Stena Drillmax ICE (UDW drillship). Well GM-ES-3 is the second well in the current drilling program and is testing a different area of the Cingulata fan system that contains the recent Zaedyus oil discovery. Results of the Priodontes exploration will allow the license partners to gain a better understanding of the area’s geology and overall potential.
S. America – Brazil
PanAtlantic to P&A Jandaia
Jan 4, 2013 – Jandaia reached its targeted depth without encountering any indication of hydrocarbons. PanAtlantic and its partner Panoro Energy have plugged and abandoned the well. Jandaia, which is located in concession BM-S-71, was the third well in Vanco’s three-well program offshore Brazil. Sabia, the first well in the program, encountered volume at the low end of the pre-drill estimate and the second well, Canario, was dry.
Jan 3, 2013 – With the Inauguration of the Tamar production platform Noble Energy and the other Tamar interest holders are one step closer to the realization of first gas which is expected in April of this year. Discovery of the deepwater reservoir took place four years ago and development has progressed on schedule and within budget. The platform was installed in 800 feet of water and has the capacity to process 1.2 bcfd from its subsea wells. Once processed, the gas will flow through 93 miles of subsea pipeline to the Ashdod Terminal on Israel’s coast. Tamar is estimated to hold 8.4 tcf of gas reserves and its development will help bring the country to the verge of energy independence.
Project Details: Tamar
N. America – US GOM
Jan 3, 2013 – LLOG Exploration awarded a subsea equipment contract to FMC Technologies relating to the recently approved Delta House development project in the deep waters of Mississippi Canyon in the US Gulf of Mexico. Under the contract FMC will supply nine subsea trees, four subsea manifolds, five multiphase meters with all associated topside control systems and subsea distribution systems. Delivery of the $114 million order will take place this year.
Project Details: Delta House
- Gulf of Mexico: FMC Technologies’ Subsea Equipment for LLOG’s Delta House Project (mb50.wordpress.com)
- With Subsea Compression Technology, Offshore Platforms Could Become Obsolete (gcaptain.com)
- UH to open first subsea engineering masters program in 2013 (appliedagrotech.net)
This week the SubseaIQ team added 1 new projects and updated 15 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
Ophir Subsidiary to Participate in Starfish
Dec 13, 2012 – A subsidiary of Ophir Energy has assumed operatorship of the Offshore Accra Contract Area through a farmout agreement with Tap Oil. Under the agreement, the Accra Contractor Group consists of: Ophir Energy (20%), Afex Oil (20%), Vitol Upstream (30%), Rialto Energy (12.5%), Tap Oil (17.5%). The farmout and transfer of operatorship have been approved by Ghana National Petroleum Corporation and the Ministry of Energy. Contract terms dictate that an exploration well must be drilled before September 23, 2013 and the Group has identified the Starfish prospect as the target of that well. Starfish is a deepwater prospect that is structurally similar to the Jubilee field. It is estimated to hold P50 reserves on the order of 431 Mmbbls.
Hess Hits Pay in Pecan-1
Dec 12, 2012 – A notice of discovery was filed with the Ghana National Petroleum Corporation on behalf of Hess Corporation for the Pecan-1 exploration well. Drilled in the Deepwater Tano / Cape Three Points license, a total depth of 15,420 feet was reached and 245 net feet of oil pay was discovered in two separate intervals. An extensive logging program was carried out and the well was sidetracked to obtain additional reservoir cores. Drilling was carried out by the Stena DrillMAX (UDW drillship) in 8,245 feet of water. The rig is now in the process of suspending the well before sailing to the Cob prospect 15 miles away.
Dec 12, 2012 – Production has commenced from Jubilee Phase 1A offshore Ghana. The first production well is onstream and has helped bring total field production to over 90,000 bopd. Phase 1A consists of five production wells, three injection wells and general expansion of the existing subsea infrastructure and should take 18 months to complete. A second Phase 1A well is expected to be brought into production before the end of the year but the Sedco Energy (DW semisub) must first perform remedial work on some of the Phase 1 wells.
Project Details: Jubilee
Asia – SouthEast
Pathum-1 Exploration Spuds Off Thailand
Dec 13, 2012 – Tap Oil announced the spud of its Pathum-1 exploration well in the G3/48 concession offshore Thailand. The well is being drilled by the Ensco 85 (300′ ILC) to a proposed total depth of 8,667 feet. Pathum is thought to hold perspective resources in the range of 5 million barrels. Barring any issues, the well should reach TD in a maximum of 11 days.
Dec 13, 2012 – Difficulties have plagued MEO Australia at its 100% owned Gurame prospect in the Seruway PSC off Northern Sumatra. After loosing over 100 feet of BHA in the Gurame SE-1X appraisal, the decision was made to plug back and sidetrack the well. More progress was made in Gurame SE-1XST but significant mud losses caused MEO to plug back into the liner at 9,599 feet. A 187 foot section of the Baong sands was perforated at 8,858 feet MDRT. No flow was observed and attempts to stimulate the well with nitrogen were made with no effect. The Ensco 85 (200′ ILC) will plug and abandon the well and will be released soon after.
Project Details: Gurame
Dec 12, 2012 – A steel cutting ceremony held at Keppel Subic Shipyard marked the start of construction of a Depletion Compression Platform (DCP) to be deployed at the Malampaya gas field near Palawan Island in the Philippines. Installation of the DCP represents Phase 3 of the Malampaya Gas-to-Power project which is led by the Philippine Department of Energy. Once complete the DCP will be stationed next to the existing Malampaya production platform. Supporting the project are Shell, as operator, and joint venture partners Chevron and Philippine National Oil Company. Keppel is responsible for building the base and topsides as well as a bridge connecting the new facility to the production platform. The DCP is expected to be installed by 2015.
Project Details: Malampaya
Dec 12, 2012 – Coastal Energy recently tested a three stage pilot hydraulic fracturing program in the Bua Ban South A-1 well. The fracked zones flowed back oil at a combined rate of 800 Bopd under natural conditions during well cleanup. Plans call for the well to be re-completed with an electric submersible pump for long term production testing. Next, the company will focus its efforts on the Bua Ban South A-3 sidetrack well in an effort to improve recovery rates. If successful, Coastal will continue the fracking program in order to unlock the full potential of the Songkhla Basin which is characterized by sands with lower porosity and permeability.
Project Details: Songkhla
Europe – North Sea
Dec 14, 2012 – Production testing has been completed on three initial development wells at the Breagh field in the UK North Sea. Results from the tests are in-line with reservoir stimulation models run by development partners RWE Dea and Sterling Resources. Once normalized to reflect expected the sales level of wellhead pressure, the current three well capacity is estimated at 88 Mmscfd. The newly drilled A3 well is the most prolific producer with a flow rate of 58 Mmscfd under initial production conditions. Performance of the development wells is being monitored so that future production can be optimized. Five wells are expected to be available by early May 2013 with an estimated total production capacity of 150 Mmscfd.
Project Details: Breagh
Dec 13, 2012 – Norwegian oil major Statoil announced Thursday that it plans to use seismic cables on the seabed to help produce 30 million additional barrels of oil from its Snorre and Grane fields. The company has signed contracts worth $160 million with U.S. firm Geospace Technologies to deliver the cables, which will be part of a permanent reservoir monitoring (PRM) program. Statoil believes the technology will allow it to better understand the reservoirs because they are stable and able to provide a more accurate picture of the subsurface than cables that are towed on the surface and which are subjected to wind, waves and currents. Statoil plans to lay more than 400 miles of seismic cables. Statoil currently recovers around 50 percent of the oil from its operated fields on the Norwegian continental shelf.
Project Details: Greater Snorre Area
Wintershall Spuds Rodriguez
Dec 11, 2012 – The Transocean Arctic (mid-water semisub) is drilling ahead at Wintershall’s Rodriguez prospect in the Halten Terrace area off Norway’s coast. Well 6407/1-6S is seeking oil in the Middle Jurassic Garn, Ile and Tilje formations. It should take roughly 75 days to reach the planned total depth of 13,254 feet. Rodriguez is located in PL475 near the Tyrihans field and Faroe’s 2010 Maria discovery. Wintershall maintains a 50 percent operating interest in the license with Faroe Petroleum and Centrica sharing 30 and 20 percent interest respectively.
Africa – Other
Dec 13, 2012 – A recent three well appraisal drilling program undertaken by BG Group and Ophir Energy on the Jodari field off Tanzania successfully achieved its objectives. The wells proved high quality reservoir across the field and reconfirmed the 3.4 Tcf mean recoverable resource estimate. In addition, the joint venture was able verify that high-angle drilling within Jodari may be a viable option to reduce development costs. Drilling was carried out by the Deepsea Metro I (UDW drillship) which is currently drilling the Mzia-2 appraisal well. Upon completion of the Mzia appraisal, the rig will return to Jodari to perform a drill stem test and then move on to continue exploratory drilling in Block 1.
Project Details: Jodari
Gas Discovery Off Romania
Dec 14, 2012 – Sterling Resources, operator of Block 13 Pelican in the Romanian Black Sea, announced a gas discovery at the Eugenia-1 exploration well. The well was drilled by the GSP Jupiter (300′ ILC) to a measured depth of 7,375 feet. Initial results indicate 72 feet of net gas pay in Late Cretaceous sandstones. Data is still being studied but open-hole logging confirmed the presence of moveable gas. The company is also interested in a 65 foot zone of Eocene limestone which presented gas shows. Attempts to collect pressure data were unsuccessful which is not uncommon in carbonates where matrix porosity is limited. The same Eocene interval turned out to be producible in an adjacent well.
Asia – South
Eni Expands Deepwater Footprint in Pakistan
Dec 13, 2012 – Through an agreement with Pakistani authorities and OGDCL, the state oil company, Eni acquired 25% and operatorship of Indus Block G in the offshore area of the Indus Basin. The block is situated in an under explored deepwater area and covers roughly 2,895 square miles. To start, Eni will initiate a multi-disciplinary study in order to establish a suitable exploration approach. Eni has maintained a presence in Pakistan since 2000 and this acquisition further strengthens its position in the country.
Kan Tan IV Secured for Offshore Taranaki Exploration
Dec 12, 2012 – OMV, operator of PEP 51906, secured the Kan Tan IV (mid-water semisub) for the third quarter of 2013 to drill the Matuku prospect offshore New Zealand. Matuku is estimated to hold 65 million barrels of mean recoverable resources. The company has undertaken several studies to de-risk the prospect. Results of the studies indicate the presence of suitable reservoir rock, and adequate seal and a mature source kitchen. Partners in the license include OMV with a 65%interest, Octanex with a 22.5% interest and NZOG who recently farmed-in for a 12.5% stake.
- The Philippines: Keppel O&M Subsidiaries Clinch S$160 Mln Contracts (worldmaritimenews.com)
- Keppel Subic Shipyard Starts Construction Works for Offshore Platform (maritime-executive.com)
- Tullow says Jubilee Phase 1 production begins in Ghana, as company’s share value reaches £11.4b (ghanabusinessnews.com)