Daily Archives: October 5, 2012

Worldwide Field Development News Sep 29 – Oct 5, 2012

This week the SubseaIQ team added 1 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.

N. America – US Alaska

Shells Announces Drilling at Sivulliq

Oct 5, 2012 – Shell announced the Kulluk (shallow-water semisub) has spud the top-hole section at its Sivulliq prospect in Alaska’s Beaufort Sea. The Noble Discoverer is currently engaged in the same type of work at the Burger prospect marking the first time in over 20 years that two rigs have been drilling off the Alaskan coast simultaneously. Last month Shell announced that its containment dome had been damaged during testing. Because of that, the rigs aren’t able to drill into possible hydrocarbon bearing formations, so for now they are restricted to drilling shallow top-hole sections in preparation for the drilling season next year.

Project Details: Torpedo and Sivulliq

Asia – Far East

Roc Oil Spins The Bit in Beibu Gulf

Oct 2, 2012 – Roc Oil Company‘s exploratory drilling program is underway in southern China’s Beibu Gulf. Well WZ6-12N-1 is being drilled in 90 feet of water to a projected depth of 5,249 feet. Up to four exploration wells well be drilled in the WZ6-12 field by the COSL 931 (300’ ILC). Upon completion of the exploratory phase, a multi-well development program will commence pending National Development and Reform Commission approval, which is expected shortly. The combined drilling program is expected to be completed during 3Q 2013.

Project Details: Beibu Gulf

Australia

Subsea 7 Wins Jurimar Development Contract

Oct 5, 2012 – Apache Australia awarded Subsea 7 a $100 million contract for the transportation, installation and pre-commissioning of subsea umbilicals, manifolds and diver-less tie-in spools for the Julimar Development Project offshore Western Australia. Project management and engineering will be handled from Subsea 7’s Perth office with offshore operations scheduled for 2014. Julimar field will be tied-in to and metered on the Chevron operated Wheatstone platform. First gas is planned for late 2016 and development is expected to continue for 20 years.

Project Details: Wheatstone

N. America – US GOM

Technip Awarded Dalmatian Development Contract

Oct 4, 2012 – Murphy Exploration & Production has awarded Technip a lump sum contract for the development of the Dalmatian field in the U.S. Gulf of Mexico. Dalmatian is located in the De Soto Canyon area in water depths ranging from 530 to 1800 feet. Scope of the project will include the engineering, project management, fabrication and installation of a gas riser, an oil riser, 23 miles of flowline and associated subsea structures. Technip will also carry out the installation and pre-commissioning of a main subsea control umbilical and infield umbilical with associated foundation and flying leads. Offshore installation is scheduled to be completed by the end of 2013.

Project Details: Dalmatian

Europe – North Sea

Providence Given Green Light For Dalkney

Oct 4, 2012 – The Irish Department of Environment, Community and Local Government awarded Providence Resources a Foreshore License for an area in the Kish Bank Basin offshore Dublin. Specifically, the Foreshore license allows Providence to conduct a 2D seismic survey, a well site survey and drill an exploration well on the Dalkey Island prospect in block SEL 2/11. Providence operates the block on behalf of its partner Petronas, each with a 50% interest. The prospect is a large undrilled structural closure at Lower Triassic level. Prolific Lower Triassic oil producers in the eastern Irish Sea off Liverpool add to the possibility that Dalkey holds oil.

Project Details: Dalkey Island

BP Flips Switch at Devenick

Oct 4, 2012 – Production systems are up and running at BP’s Devenick gas project in the central North Sea. The HPHT project is in the process of ramping up to full production – estimated to peak in 2013 at 100 million cubic feet per day. When producing at the maximum rate, Devenick will add an extra 3% to the UK’s total gas production. BP and partner RWE Dea have invested $1 million in the project which has largely been serviced by UK based companies. Gas is routed from a subsea manifold through an insulated pipeline to the Marathon-operated East Brae platform. It is estimated that the field holds 430 billion cubic feet and will maintain production until 2025.

Project Details: Devenick

Fairfield Optimistic About Dunlin Enhancements

Oct 4, 2012 – To date, Farifield Energy has invested $113.3 million in an effort to revitalize the Dunlin platform. For the first time since early 2000, the operator will be able to use its own independent power generation system to achieve significantly higher and sustained water injection performance. A new fuel gas import system and modified water injection system are expected to boost production of the mature field to around 10,000 bopd. Additional work has included platform and subsea modifications and a recent acquisition of a new 3D seismic survey over the field. The data will help support an exploration program that could result in additional wells being drilled and tied-back to the platform.

Project Details: Dunlin

Aker Grabs Visund Subsea Work

Oct 4, 2012 – Aker Solutions has been awarded a $52.6 million contract by Statoil for the delivery of five subsea trees and 11 control modules to the Visund field on the Norwegian continental shelf. Included in the contract is an option for four additional subsea trees. The contract is a call-off from an existing frame agreement between the two companies signed in 2007. The trees will incorporate Aker’s most advanced subsea technology which will facilitate oil and gas production at a more efficient level and allow greater recovery of reservoir data. Manufacturing of the Visund trees and control modules will take place at Aker Solution’s Tranby and Aberdeen facilities respectively.

Project Details: Greater Gullfaks Area

Total Bringing Atla Online Soon

Oct 2, 2012 – The 1.4 billion cubic meter-Atla gas and condensate field is expected to be brought on line in the first half of October according to Total, the field operator. Atla will be utilized via a subsea template tied back to an existing pipeline between the Skirne subsea facilities and the Heimdal Gas Center. The original exploration well was drilled into the Brent formation and is now being re-used as a production well.

Project Details: Atla (David)

Faroe Secures Rig for Novus

Oct 2, 2012 – Faroe Petroleum contracted the West Navigator (UDW drillship) to drill an exploration well at their Novus prospect during the second half of 2013. The prospect is located in the productive Halten Terrace hydrocarbon region offshore Norway and covers blocks 6507/7 and 6507/10 of production license 645. Partners in the license include Centrica (40%) and Skagen (10%). Primary objectives of the well will be the Jurassic reservoirs of the Garn, Ile and Tilje formations. Novus will be Faroe’s second operated well on the Norwegian continental shelf.

Project Details: Novus

Statoil Says No Increase for Melkoya Capacity

Oct 2, 2012 – Norwegian oil major Statoil announced Tuesday that it and its partners have decided to stop work on a capacity increase at the Melk??ya facility serving the Sn??hvit license in the Barents Sea after they concluded that current gas discoveries do not justify the expansion of the field. Statoil said that over the last 18 months, the Sn??hvit license partners carried out studies for the expansion of gas exports from the field, and that increased capacity would enable the accelerated gas production of increased reserves in the Sn??hvit license. Thorough studies were carried out both on an LNG train and a dew-point facility/pipeline solution, while considerable resources were devoted to finding solutions that could make a capacity expansion possible. However, the license partners have now decided the immediate future will focus on optimizing and upgrading the existing LNG facility at Melk??ya. Statoil, the operator, holds 36.79 percent of the Sn??hvit license, while Petoro, Total E&P Norge and RWE Dea Norge hold 18.4 percent, 12 percent and 2.81 percent respectively.

Project Details: Snohvit

Dana Adds to Stake in Bittern

Oct 2, 2012 – Dana Petroleum recently announced it has taken over operatorship of the Triton FPSO from Hess. The Triton FPSO serves the Bittern, Guillemot West and Northwest, Clapham, Pict and Saxon fields. As part of the agreement, Dana also acquired Hess’ 28.28% stake in the Bittern field bringing Dana’s interest in the field to 33%. The acquisition is keeping in line with the company’s strategy of moving from mainly non-operated to fully operated activities in the UK North Sea.

Project Details: Triton FPSO

Marathon Receives PSA Consent for Vilje

Oct 1, 2012 – Consent has been granted by the Petroleum Safety Authority Norway (PSA) allowing Marathon Oil to assume operatorship of the Vilje field in block 25/4 of production license 036D. Vilje has been developed via two subsea wells connected to the Alvheim FPSO. Marathon is now the operator of three producing fields offshore Norway. Partners in the field consist of Statoil with a 28.8% stake and a 25.2%-stake for Total. Additionally, the partners have decided to develop Vilje South through a single development well and standard subsea template.

Project Details: Alvheim

More Success with Johan Sverdrup Appraisal

Oct 1, 2012 – Well 16/2-13A, the sidetrack of appraisal well 16/2-13S, has proven excellent reservoir quality and thickness in the PL501 area of the Johan Sverdrup field. Lundin Petroleum indicates results from the well have validated the field geologic model and confirmed a deeper oil-water contact in that area. A comprehensive coring and logging suite was carried out and helped confirm a gross reservoir column of 72 feet. The sidetrack was drilled to a depth of 9,107 feet and now both wells will be plugged and abandoned.

Project Details: Johan Sverdrup

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USGS Releases Survey on Utica Shale Gas Resources, USA

The Utica Shale contains about 38 trillion cubic feet of undiscovered, technically recoverable natural gas (at the mean estimate) according to the first assessment of this continuous (unconventional) natural gas accumulation by the U. S. Geological Survey.

The Utica Shale has a mean of 940 million barrels of unconventional oil resources and a mean of 9 million barrels of unconventional natural gas liquids.

The Utica Shale lies beneath the Marcellus Shale, and both are part of the Appalachian Basin, which is the longest-producing petroleum province in the United States. The Marcellus Shale, at 84 TCF of natural gas, is the largest unconventional gas basin USGS has assessed. This is followed closely by the Greater Green River Basin in southwestern Wyoming, which has 84 TCF of undiscovered natural gas, of which 82 TCF is continuous (tight gas).

“Understanding our domestic oil and gas resource potential is important, which is why we assess emerging plays like the Utica, as well as areas that have been in production for some time” said Brenda Pierce, USGS Energy Resources Program Coordinator. “Publicly available information about undiscovered oil and gas resources can aid policy makers and resource managers, and inform the debate about resource development.”

The Utica Shale assessment covered areas in Maryland, New York, Ohio, Pennsylvania, Virginia, and West Virginia.

Some shale rock formations, like the Utica and Marcellus, can be source rocks – those formations from which hydrocarbons, such as oil and gas, originate. Conventional oil and gas resources gradually migrate away from the source rock into other formations and traps, whereas continuous resources, such as shale oil and shale gas, remain trapped within the original source rock.

These new estimates are for technically recoverable oil and gas resources, which are those quantities of oil and gas producible using currently available technology and industry practices, regardless of economic or accessibility considerations.

This USGS assessment is an estimate of continuous oil, gas, and natural gas liquid accumulations in the Upper Ordovician Utica Shale of the Appalachian Basin. The estimate of undiscovered oil ranges from 590 million barrels to 1.39 billion barrels (95 percent to 5 percent probability, respectively), natural gas ranges from 21 to 61 TCF (95 percent to 5 percent probability, respectively), and the estimate of natural gas liquids ranges from 4 to 16 million barrels (95 percent to 5 percent probability, respectively).

USGS is the only provider of publicly available estimates of undiscovered technically recoverable oil and gas resources of onshore lands and offshore state waters. The USGS Utica Shale assessment was undertaken as part of a nationwide project assessing domestic petroleum basins using standardized methodology and protocol.

USGS Releases Survey on Utica Shale Gas Resources, USA LNG World News.

Cummins Westport Begins Developing New Gas Engine, Canada

Cummins Westport announced it has begun development on the ISB6.7 G, a mid-range 6.7 liter natural gas engine designed to meet the increasing demand for on-highway vehicles powered by lower cost, cleaner and increasingly abundant natural gas. As a leading supplier of natural gas engines, Cummins Westport Inc. continues to expand its product range to supply the growing demand for natural gas engines.

The ISB6.7 G engine will be based on the Cummins ISB6.7 diesel engine and will use Cummins Westport’s proven spark-ignited, stoichiometric cooled exhaust gas recirculation (SEGR) technology. Exhaust aftertreatment will be provided by a simple, maintenance-free three-way catalyst.

The engine will run on compressed natural gas (CNG), however, the natural gas may be stored on the vehicle in liquefied natural gas (LNG) state or as CNG. The ISB6.7 G is expected to be in production by 2015 and will be designed to meet Environmental Protection Agency (EPA) and California Air Resources Board (CARB) regulations in force at the time of launch.

“The addition of the ISB6.7 G will round out our family of high performance natural gas engines,” said Jim Arthurs, President of Cummins Westport. “It joins the 8.9-liter ISL G, with over 16,000 engines in service, and the 11.9-litre ISX12 G, which will start production in 2013, to give our customers a broad range of natural gas engines for on-highway applications.”

Cummins Westport Begins Developing New Gas Engine, Canada LNG World News.

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