Current Projects
Ichthys – Australia
The Ichthys Field in the Browse Basin offshore Western Australia first demonstrated its potential to be a world-class gas project in 2000. Since then, most likely resource estimates have grown to 12.8 tcf of gas and 527 million barrels of high value condensate.
In September 2008, INPEX (Operator, 76%) and its joint venture partner Total (24%), selected Darwin as the site for the LNG processing facility.
A Final Investment Decision (FID) on the Project was reached in January 2012, with construction set to begin shortly.
The Ichthys Project will deliver significant social and economic benefits to Australia. The project will bring jobs and training, business opportunities, new infrastructure and advanced technology - building capacity for the nation’s energy industry
Please contact our Perth office for more information. Click here
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Masela Block (Abadi) Indonesia
The Abadi-1 exploratory well was drilled in 2000 and confirmed the presence of gas and condensate. This marked the first discovery of crude oil and natural gas in the Arafura Sea, Indonesia. Subsequently six appraisal wells were drilled by 2008 (two in 2002 and four more in 2007- 2008), and gas and condensate were successfully confirmed in all of the wells. In September 2008, based on the results of Pre-FEED of a floating LNG, a development plan was submitted to the Indonesian Government and approval in principle was granted. After a thirdparty evaluation, approval for the plan of development (POD-1) was granted in December 2010 for commencement of LNG production of 2.5 million tons/year.
Currently, various preparatory measures, including Front-End Engineering and Design (FEED) and Environmental and Social Impact Assessment (AMDAL), are underway in the lead-up to development of the Abadi gas field
Please contact our Singapore office for more information. Click here
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Golden Eagle – UK North Sea
The Golden Eagle development encompasses both the Golden Eagle and Peregrine reservoirs located in central North Sea blocks 20/1N, 20/1 and 14/26a, approximately 43 miles from Aberdeen. The development plan for Golden Eagle incorporates a combined production, utilities and accommodation platform linked to a separate wellhead platform. Plans call for 20 development wells (16 platform-based and four subsea) to be drilled. The development will also include associated in-field and export pipeline infrastructure.
Detailed design engineering has commenced and fabrication is scheduled to start in late 2011. Pipeline and subsea installation is expected to begin in early 2013, to be followed by drilling later that same year. First oil production is forecast for late 2014 and the development is expected to have an initial gross production rate of up to 70,000 barrels of oil equivalent per day (boe/d), about 26,000 boe/d net to Nexen.
Please contact our Manchester office for more information. Click here
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Jasmine – UK North Sea
The field is planned to be developed in three phases. In the first phase, the West Limb and the Northern Terrace sections of the field will be developed. Drilling activities for the first phase are expected to start in the second quarter of 2011.
Installation of the Jasmine wellhead platform, the Judy riser platform and the multiphase Jasmine pipeline will be carried out in the first phase.
Please contact our Manchester office for more information. Click here
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Papau New Guinea LNG
PNG LNG is an integrated development that includes gas production and processing facilities in the Southern Highlands and Western Provinces of Papua New Guinea, including liquefaction and storage facilities (located northwest of Port Moresby on the Gulf of Papua) with capacity of 6.6 million tons per year. There are over 700 kilometers (450 miles) of pipelines connecting the facilities.
The investment for the initial phase of the Project, excluding shipping costs, is estimated at US$15 billion. Over the life of the Project, it is expected that over nine trillion cubic feet of gas will be produced and sold.
Please contact our Port Moresby office for more information. Click here
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Kashagan Oil Field
Kashagan Field is an offshore oil field located in Kazakhstan.[1] The field is situated in the northern part of the Caspian Sea close to the Kazakhstan city of Atyrau. The field was discovered in 2000 and was one of the larger discoveries in that decade,
The development plan for the $136bn project, approved in February 2004, foresees production developing in three phases for reserves of seven billion barrels, which could rise to 13 billion through the partial re-injection of gas.
Production is forecast to start in late 2012, building up from 75,000bpd to a peak by about 2021 of 1.5 million bpd – slightly more than Kazakhstan's total current production.
Please contact of Atyrau office for more information. Click here
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West Qurna – Iraq
West Qurna is one of Iraq's largest oil fields, located north of Rumaila field, west of Basra. West Qurna is believed to hold 43 billion barrels (6.8×109 m3) of recoverable reserves, making it the second largest field in the world after Saudi Arabia's Ghawar oil field.
As per Iraqi Oil Ministry estimates, the project will require a $25 billion investment and another $25 billion in operating fees creating approximately 100,000 jobs in underdeveloped southern region. ExxonMobil is set to increase the current production of 0.27 to 2.25 million barrels per day (43×103 to 358×103 m3/d) within seven years.
Please contact our Basra office for more information. Click here
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Barzan Natural Gas Project, Qatar
The Barzan Gas Project is strategically important for the long-term sustainable development of the State of Qatar. It will be completed in two phases: Train One will come on-stream in 2014 and Train Two in 2015. When completed the two new processing trains together with other RasGas facilities (liquefied natural gas and pipeline sales gas) will produce around 11 billion standard cubic feet per day.
Please contact our Doha office for more information. Click here
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Hadrian:
ExxonMobil is developing the Hadrian South natural gas discovery as a subsea tie-back to a planned host facility on Anadarko’s Lucius field near to the north in the Keathley Canyon area of the deep-water Gulf of Mexico.
Hadrian is located in the Keathley Canyon Blocks in 7,380 feet of water. In early 2010, drilling encountered oil and natural gas at the Hadrian North in KC919 and extending into KC918, with over 550 feet of net oil pay and a minor amount of gas in high-quality Pliocene and Upper Miocene sandstone reservoirs. In 2009, 200 feet of natural gas pay in Pliocene sandstone reservoirs at the Hadrian South prospect in Keathley Canyon block 964 was discovered. Estimated recoverable reserves are 700 million barrels of oil equivalent.
ExxonMobil has awarded Technip a subsea contract for its Hadrian South development. Technip will undertake project management, procurement and installation of two seven-mile long flowlines and associated jumpers, installation of a nine mile umbilical, associated foundation and flying feeds as well as pre-commissioning of the project. The contract will be executed out of Technip’s operating centre in Houston, Texas, while the flowlines will be welded at its spoolbase in Mobile, Alabama. Subsea equipment is scheduled to be installed in 2013 using the company's Deep Blue deep water pipelay vessel.
Please contact our Houston office for more information. Click here
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Kearl:
Located 70 km north of Fort McMurray is the Kearl oil sands project, jointly owned between Imperial Oil (operator) and ExxonMobil Canada. It will be one of Canada’s largest open-pit mining operations with regulatory approval for up to 345,000 barrels a day of production.
The proposed development will be an open pit mining operation, which will be developed in three stages. At the first stage it will produce approximately 110,000-barrel-per-day (17,000 m3/d), with later expansions to more than 300,000 barrels per day (48,000 m3/d). Blended bitumen from the Kearl project will be transported to the Edmonton area by Enbridge’s pipeline system.
The Kearl project is similar in design to existing oil-sands mines in the Fort McMurray region, using large-scale shovels, trucks, crushers and oil-sands hydro transport technology. With 4.6 billion barrels of recoverable bitumen resource, Kearl is one of Canada’s largest and highest quality oil sands deposits.
Phase one of the project is actively in the construction phase with project start up targeted for 2012. Phase two of the project is currently in the Detail Design.
Please contact our Canada offices for more information. Click here
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Hebron:
The Hebron field is located 350 km offshore Newfoundland and Labrador. Oil field with minimum recoverable reserves estimated at 660 million barrels and a maximum of 1.05 billion barrels. Production is expected to hit about 150,000-170,000 bpd. Hebron is challenging due to Heavy oil and complex reservoirs. The Canada-Newfoundland and Labrador Offshore Petroleum Board (C-NLOPB) estimates that the development contains 570 million barrels of recoverable oil. First oil is due to flow between 2016 and 2018. The initial development is expected to focus on Hebron and West Ben Nevis. The Ben Nevis field is a possible future satellite tie-back.
The Hebron field will be developed using a stand-alone concrete GBS (gravity-based structure). The GBS will consist of a reinforced concrete structure designed to withstand sea ice, icebergs, and meteorological and oceanographic conditions at the offshore Hebron Project Area.
The project is in the advanced stages of FEED and is moving into the next phase of Detailed Engineering and Procurement. Fabrication is scheduled to start late 2012.
Please contact our Canada offices for more information. Click here