From the Editor Archive Collections

“Our innovative products and services for the oil drilling industry have already set us apart, but winning the Queen’s Award for International Trade is an independent endorsement of what the company has achieved,” said Tony Cutmore, Managing Director of Centek. “This is recognition of Centek as a top performer at the highest level of business professionalism, both here and abroad, and I am exceptionally proud of all our people.”

Centek manufactures casing centralisers, which are used in oil and gas drilling to position pipes down the drilled hole prior to cementation. The company was founded in 2001, and in the three years from 2004 its export sales have more than doubled, with 77 per cent of its business coming from outside the UK. Centek sells its products both direct and through distributors, and it has collaborative agreements with one of the World’s largest service and supply companies in the oil industry.

Centek emphasises product quality and customer support, and 80 per cent of its sales in the company year ending 31st October 2007 were repeat orders from existing customers. Centek has achieved ISO 9001-2000 and API SPEC 10 D – 0022 certification, both essential competencies in the oil industry.

The Queen's Awards for Enterprise are the UK's most prestigious awards for business performance, and are awarded for achievements in three categories: International Trade, Innovation and Sustainable Development. www.centekltd.co.uk

The value of the new contract is estimated to be approximately US$500 million (£250 million) over the five years. Under the contract, which is an extension of an existing eight-year contract, AMEC will provide engineering and construction management services to enhance and extend the life of all of BP's offshore installations in the Azeri sector of the Caspian Sea, which represents around 20 per cent of BP's global production.

The facilities include the Chirag, Central Azeri, West Azeri, East Azeri and Shah Deniz and the soon-to-be-developed Deep Water Guneshli assets, which are of strategic importance to Azerbaijan. Together, they currently produce over 1 million barrels of oil and 700 million standard cubic feet of gas per day.

AMEC's expertise in asset support and brownfield projects, excellent safety performance and a major presence in Baku, where it has developed a sustainable regional business, were important factors in AMEC winning the contract renewal.

"This is an important long-term asset support contract that reinforces our international growth strategy and our relationship with BP,' said Neil Bruce, Chief Operating Officer, AMEC's Natural Resources business. 'We have developed and continue to develop a strong position in the Caspian and surrounding region, where we have strong business relationships and a good understanding of local issues." Richard Rippon-Swaine, Azerbaijan Country Manager, AMEC's Natural Resources business added: "This latest contract underlines our excellent position in Azerbaijan. Since setting up in Baku 10 years ago, we have built a business that employs local people and delivered several successful major projects that have helped Azerbaijan's national oil industry to grow."

The new boat is scheduled for delivery from the shipyard in December 2009, but will likely go out on the spot market for a few months before starting its contract with StatoilHydro during the first quarter 2010.

“We are very pleased that many ship owners are following up with StatoilHydro’s emphasis on increasing safety for onboard crews by emphasising new technology,” says Morten Meinich, StatoilHydro marine operations head.

“The ship has state-of-the-art technology that enhances safety on deck during anchor-handling operations, including cargo rail manipulators which reduce manual work. The vessel also has hybrid engine solutions and catalytic converters that reduce nitrous oxide (NOx) and CO2 emissions. It has many uses, including anchor handling in deep waters, ROV operations and supply duties,” comments Meinich.

The contract is valued at between GBP 20 and 30 Million annually and will create around 100 new jobs. The award to one of the Aberdeen businesses of the global engineering and construction group comes in the wake of Fairfield's purchase of the Dunlin field cluster from Shell in December 2007.

Aker Solutions will undertake a number of initial studies on the installation, followed by an aggressive programme of modifications, including onshore engineering work, procurement and offshore construction. In delivering the contract Aker Solutions will be working very closely with Amec as the Dunlin platform duty holder.

The Dunlin oilfield is situated 195 km north-east of Lerwick, with first production in August 1978 from the Dunlin Alpha platform.

Rod Buchan, managing director for Aker Solutions maintenance, modification and operation business in Aberdeen said: "Fairfield Energy is a new client for us and is taking over its first North Sea asset. Our success in winning this work is very much aligned with our key strategic goals, one of which is to develop relationships with independent operators and new entrants to the UKCS. This award underlines our position as a leading modifications company in the North Sea and as the preferred partner of independent operators.

"Fairfield is a new entrant with ambitions to become a key North Sea operator, and we look forward to supporting their plans to achieve significant growth over the coming years and to delivering significantly increased value from the Dunlin asset."

This contract itself involves the abandonment of 2 platforms with associated wells and the removal of pipelines and subsea tie-ins. In addition to this, Proserv A&D have also been appointed in their project management and contracting capacity to ensure this project is managed safely, time efficiently and within budget. Huey Kliebert Vice President of Abandonment Services states “Proserv’s extensive abandonment and contracting services’ expertise and experience, positions Proserv A&D as a leader in the Gulf of Mexico. Our decommissioning, contracting, engineering and abandonment services are highly recognised globally as being able to deliver full decommissioning packages.”

These projects are due to take place concurrently in both the Ship Shoal and High Island blocks, where water depths are 37 and 194 feet respectively. Proserv A&D will provide total marine management of this project. This includes simultaneously mobilising both the appropriate lift boats, well abandonment personnel and the required equipment necessary to conduct the well abandonment and structural removals in both locations. Upon completion of these operations, Proserv will then synchronise the employment of a 1300 ton Derrick Barge, a diving crew and a dive support vessel in order to remove the platform, and abandon the pipeline and associated subsea tie-in.

The three-year contract calls for the provision of directional drilling, logging-while-drilling, cementing, logging and perforating, coiled tubing and stimulation services for 93 wells offshore Northeast Saudi Arabia. The offshore component of this project will utilize 10 jack-up rigs. The Manifa project is a key part of Saudi Aramco's plan to increase its overall production capacity.

Ahmed Lotfy, Halliburton's Eastern Hemisphere president, said: "To be selected by Saudi Aramco for yet another project of this magnitude demonstrates our client's continued confidence in our ability to successfully execute such complex and challenging operations. This contract award validates our commitment to expand customer relations with national oil companies and grow Halliburton's international business."

"Halliburton has worked with Saudi Aramco for nearly 70 years and has maintained an impressive track record of safely and successfully delivering mega-projects," added Gasser Badrashini, vice president of Halliburton's Saudi Arabia and Bahrain operations. "Following on from the success of our work on the Khurais mega-project, which is currently ahead of schedule, the award of the Manifa project reflects our solid performance and leading technologies."

"We are extremely pleased to be awarded these four contracts with major clients. This proves our capability to deliver our well proven process systems in a booming market," says Per Harald Kongelf, President for Aker Solutions' process systems business.

Two of the contracts have been signed with Mitsui Ocean Development & Engineering Co., Ltd (MODEC) for delivery of process modules to an FPSO. It is an EPC contract of the Aker Solutions Sulphate Removal Unit (SRU) and a Mono Ethylene Glycol (MEG) reclamation unit. These contracts are a breakthrough for our MEG technology in the FPSO market and they also strengthen the relationship between MODEC and Aker Solutions. Deliveries are scheduled to first half of 2009.

Aker Solutions has also signed a contract with Woodside for delivery of MEG reclamation system to Woodsides Pluto project. Pluto is an offshore gas field in North-Western Australia with an onshore Liquified Natural Gas (LNG) plant. The key proprietary equipment will be delivered in autumn 2008 with a gas production start scheduled to begin in the first quarter of 2010.

In addition, Aker Solutions will deliver crude oil dehydration system to OAO Globalstroy, a leading Russian construction company. Globalstroy is working under an EPC contract with the largest Russian crude producer, Lukoil. This will be the third contract signed with Lukoil to date and the most significant. As a specialist in heavy oil processing, Aker Solutions regards Russia and Kazakhstan strategic markets for the provision of our equipment and services. The company continues to pursue numerous other prospects with key customers in these markets.

The work will be undertaken by the Aker Solutions subsidiary, Aker Process Systems. These contracts were booked as order intake in first quarter 2008.

Under the agreement, FMC Technologies will manufacture and provide subsea production systems, engineering and life-of-field services for various offshore projects that LLOG is developing throughout the Gulf of Mexico, including MC72, Green Canyon 448 and Mississippi Canyon 503.

“We have enjoyed serving as LLOG’s preferred provider for the last several years,” said John Gremp, executive vice president of energy systems at FMC Technologies. “The signing of today’s alliance agreement comes only weeks after LLOG announced they had identified three new deepwater discoveries in the Gulf of Mexico. We’re excited about formalizing our alliance and welcome the opportunity to assist LLOG in developing their discoveries in the Gulf.”

For further information please visit - http://www.fmctechnologies.com/

Based on the data gathered in the Bo-3X well, studies will now be initiated to determine if the encountered hydrocarbons are commercial and if a possible development can be integrated with the ongoing development of the Valdemar - Bo Field.

Senior Vice President Anders Würtzen says: "We welcome the encountered hydrocarbons in the Bo-3X well and hope to have the commerciality confirmed. Drilling of the well was based on application of high-resolution 3D seismic data and innovative interpretation techniques.”

“Today’s announcement helps further solidify Enbridge as a leader in the development of energy delivery infrastructure in North America,” said Patrick D. Daniel, President and Chief Executive Officer, Enbridge Inc. “The Line 4 Extension complements Enbridge’s major expansion projects to enhance market access for Western Canadian crude oil production. Together with our Alberta Clipper Expansion and Southern Access Projects, Line 4 is a key component in expanding our mainline system capacity, strengthening the connection between secure, reliable energy from the Canadian oilsands and U.S. refining markets.”

Approval of the Line 4 Extension follows the recent NEB approvals of Enbridge’s Alberta Clipper Expansion and Southern Lights projects. With 1,607 kilometres (1,000 miles) of new pipeline construction, Alberta Clipper is the largest expansion project in Enbridge's history and is designed to move crude oil from a secure, stable North American source to U.S. Midwest markets.

Roxar Fieldwatch is a specialized Windows-based field monitoring system enabling E&P operators to ‘watch their fields’ remotely, and Roxar Fieldmanager is a comprehensive production data management system, allowing them to manage and interpret the field’s data. Both solutions are built on Roxar’s data acquisition technology, DACQUS®. The rapid retrieval and display capabilities of both applications will also give the user the ability to quickly visualize the data and identify trends, patterns or areas of interest for further analysis. The result will be increased information and reduced uncertainty when making crucial production optimization and reservoir management decisions. Said Roxar CEO, Gunnar Hviding: “E&P companies today require a complete picture of their reservoir, but are all too often overwhelmed by raw data with a single oil or gas field generating up to one terabyte of data per day . Whether it is temperature, pressure or flow rates, Roxar Fieldmanager and Fieldwatch are playing a crucial role in transforming this raw data into valuable decision-making information and providing a complete solution from field instrument through to desktop.” “With today’s E&P operator demanding an integrated, reservoir monitoring and asset management system, where the economic impact and risk of reservoir management decisions can be fully assessed, the timing of Roxar Fieldmanager and Fieldwatch’s market introduction could not have been better.”

The agreement covers a Contract Area of approximately 184,300 acres representing 75 percent of the license. ExxonMobil will have a 67 percent interest in the Contract Area and is the operator. TXM retains 33 percent of the Contract Area and 100 percent of the remaining license outside the Contract Area.

Under the terms of the agreement, ExxonMobil will conduct an initial work program to test existing wellbores and/or drill additional wells if needed to evaluate commercial production of unconventional gas and liquid hydrocarbons. ExxonMobil will invest $75 million in this initial phase, scheduled to begin this year.

After the initial work program, the agreement includes options for ExxonMobil to elect to follow with appraisal and development programs.

“ExxonMobil is pleased to add the Mako Trough in Hungary to our global portfolio of resource opportunities,” said Elwyn Griffiths, vice president, business development, ExxonMobil Exploration Company. “Effective pursuit and capture of a wide variety of opportunity types underpins ExxonMobil’s ability to deliver reliable, affordable energy to satisfy the world’s long-term and growing energy demand.”

The scope of work for this contract includes the fabrication and loadout of the 22,000MT jacket (including buoyancy tanks), 18,900MT of piles and the bridge link (approximately 100m long) to the North Rankin A Platform. Contracts of this nature are typically valued in excess of US$100 million.

“Completing the NRB substructure will be a major milestone for our Batam Island, Indonesia facility as this will be the largest jacket ever built in the Southeast Asia region,” said Scott V. Cummins, Vice President and General Manager, Asia Pacific “This award confirms our strong working relationship with Woodside. Their decision to award us this project underscores Woodside’s confidence in our ability to deliver large structural projects on time.”

The North Rankin Redevelopment Project will provide additional compression to unlock low pressure reserves from the North Rankin and Perseus gas and condensate fields off Karratha, Western Australia.

The NRB project, once completed will ensure continued gas supplies to the North West Shelf Venture’s liquefied natural gas facilities. Construction work will be performed at J. Ray’s facility on Batam Island, and is expected to begin in the fourth quarter of 2008. At the peak of construction, 1,300 people are expected to work on the project.

”The development of compact seabed separation plants is key to success in deep waters, such as in the Gulf of Mexico and off Brazil,” says the activity leader of the CompactSep JIP project, Olav Kristiansen, at StatoilHydro’s research and development centre in Trondheim.

Seabed processing allows tasks such as separation, pumping and compression to be performed on the seabed rather than on the platforms. The project aims to develop a plant that will work in water depths down to 2500–3000 metres. Traditional separators are too heavy to be lifted down into such deep waters. They will also get a bulky wall thickness due to great external pressure. Reducing the weight and dimensions is crucial.

”We will build a three-metre high, six-metre long demonstration rig for extensive laboratory and function tests, using model fluids and real fluids, both under low and high pressure,” Kristiansen says.

The first tests will take place in StatoilHydro’s research and development laboratory in Trondheim. The entire separation system will then be tested in a high-pressure rig at the SINTEF research foundation, where larger high-pressure facilities exist. Finally, StatoilHydro’s research and development centre in Porsgrunn will take over. Full-scale testing of the plant, using real gas and oil types, will be performed here. Parts of the system will at the same time be tested with well stream on the Gullfaks C platform in the North Sea.

The research project is managed and performed by StatoilHydro as a joint industry project (JIP), with the three companies as equal partners. The contract is based on the existing technology cooperation agreement recently signed with Petrobras and Chevron. The project, with a cost limit of NOK 54 million, will run until 2011.

In the Ebla project, Petro-Canada is operator with a 100% interest in a production sharing contract to develop and produce natural gas from the Ash Shaer and Cherrife fields. First gas is scheduled for delivery in 2010.

Subsequent to the contract award, Petrofac’s Energy Developments division has agreed in principle with Petro-Canada to purchase a 10% interest in the Ebla production sharing contract, subject to the approval of the Syrian government.

The Ebla gas treatment plant will be located in the Ash Shaer field between Homs and Palmyra. The initial contract, which will last just over two years, will include all associated facilities and infrastructure, including engineering, procurement and construction, commissioning and start-up assistance of the gas treatment plant, pipelines, gas gathering station flow lines and well sites. The Ebla plant will be designed to produce 88 million standard cubic feet of sales gas per day, 150 tonnes of liquid petroleum gas per day and handle the associated condensate; sales gas and condensate will be fed into the Syrian pipeline grid and LPG will be transported via tankers.

Commenting on the award, Maroun Semaan, Chief Executive, Petrofac Engineering & Construction, said: “This is another significant award in Syria for Petrofac which, taken together with the Jihar gas plant award, provides us with almost US$1 billion of work in a country where we have successfully worked on a number of projects. It confirms our position as a leading and successful contractor in the gas processing sector.”

Ayman Asfari, Petrofac’s Group Chief Executive added: “We are delighted to have been offered the opportunity to partner with Petro-Canada and the Syrian Government and we look forward to demonstrating the benefits of our integrated service offering on this exciting development.”

Peter Kallos, Petro-Canada’s Executive Vice-President, International & Offshore, commented: “We are very pleased to have Petrofac’s involvement on this project, which offers significant potential to Petro-Canada and our partners but has a demanding schedule for delivery of first gas. This agreement will be a major factor in successful execution of the project.”

The project – worth around £1.5 million – saw Opus install a fully integrated, skid-mounted CFU, including Mare’s Tails, to treat two separate streams onboard the Hess-operated Triton FPSO (Floating Production Storage and Offloading) vessel, located in the UK sector of the North Sea. The project – which aims to reduce the concentration of oil in produced water from Triton – has been hailed a great success.

Opus Maxim’s compact flotation technology has assisted Triton in improving the quality of waste water, which occurs naturally in oil and gas reservoirs, enabling Hess to meet rigorous environmental standards. The Opus CFU treatment system achieved up to a 94% removal efficiency, reducing oil-in-water content on the outlet down to 10ppm (parts per million).

Nigel Weir, managing director of Opus Maxim, says he is extremely pleased with the results from the Triton commissioning, particularly as they were achieved in challenging conditions.

He said: “The robustness of the Opus system was really tested under demanding offshore conditions. Start-up and process control is excellent and the operation is very stable - we experienced wide transient inlet conditions which included varying flow rates, oil and solids inlet loading and motion. “The CFU work on Triton was undertaken during heavy seas – with Storm Force 10 gales hitting the local area at the time of commissioning – but the team, together with the technology, successfully achieved the operational and contractual objectives.

“The rocking motion of a ship can have a detrimental effect on oil/water separation and Opus’ CFU technology has been developed to withstand these conditions and so is ideal for FPSO applications.”

Mr Weir added that he believes the successful completion of the Triton project heralds the start of an exciting period for the company. He said: “We are thrilled this major project has been delivered so successfully, as our compact flotation technology has undergone an intensive and meticulous research and development programme.

“We are already working on a number of similar projects on platforms in the North Sea and with ongoing research and development to develop the technology further still, I am confident our CFU technology will play a major role in the continued growth and future success of Opus in years to come.” For further information about Opus Maxim Ltd please call 01483 414 037 or visit www.opusmaxim.com

The contract is expected to commence during July 2008 in direct continuation of the rig's current contract commitment, also with the Total subsidiary offshore Angola. Revenues that could be generated over the five-year contract, inclusive of a performance bonus opportunity of up to five percent of the contractual operating dayrate, total approximately $862 million, excluding revenues for mobilization, demobilization and client reimbursables.

The Pride Angola is one of eight deepwater drillships and semisubmersibles in Pride International's fleet, six of which are dynamically positioned units. The rig, which is designed for operating in water depths of up to 10,000 feet, but currently equipped for drilling operations in 6,000 feet of water, has been under contract to Total's Angola subsidiary since it entered service in 2000. The rig has achieved an operating and safety performance that ranks among the industry's best, including less than 1.5% mechanical downtime since January 2001 and no lost-time incidents since May 2002. The impressive operating performance has resulted in the rig realizing greater than 95% of its bonus opportunity since commencing operations.

West Sirius was delivered within 30 days from original delivery schedule, while West Phoenix, due to customer initiated modifications, was delivered approximately three months after original contract date. Both drilling rigs were delivered with only minor deviation to the budget which was agreed when the rigs were fixed to the charterer.

The units will proceed for mobilization, and estimated time of arrival for West Phoenix in the North Sea is in the beginning of the third quarter 2008, and estimated time of arrival for West Sirius in the Gulf of Mexico at the end of the second quarter 2008. Both drilling units have secured long-term contracts. West Phoenix has a three-year contract with Total Norge to utilize the unit in the North Atlantic region. West Sirius has a four-year assignment with Devon Energy Corporation to utilize the unit in the Gulf of Mexico.

West Phoenix and West Sirius are both sixth generation, deepwater, state of the art drilling units and some of the most advanced drilling rigs ever built, based on proven designs and performance.

The drilling units belong to a high specification, new generation drilling units, focusing on a broader spectre of capabilities, a larger operating area, a high load carrying capacity, decreased dependence on frequent supplies, efficiency and improved safety and working environment as well as a special environmental focus, minimizing the exposure to the environment. The drilling units are designed with a dynamic positioning system and a water depth capability up to 3,000 meters. In addition, West Phoenix is designed with a dual derrick and is constructed for winter operations in northern and arctic areas.

Commenting on the delivery, Chief Executive Officer in Seadrill Management AS, Kjell E Jacobsen said, "Seadrill has reached a highly important milestone with the delivery of the first two newbuild deepwater drilling units out of eight units to be delivered this year." Project costs for each of the two units are in line with what have been previously reported.

Upon commencement of the contracts, Seadrill will invoice their two customers approximately US$70 million in mobilization payments. Chairman John Fredriksen in Seadrill Limited says in a comment, "The completion of the two newbuilding projects confirms the Seadrill organization's ability to manage complex projects within time and cost and is a great achievement for our organization and the people involved. It also confirms that the Seadrill strategy to order newbuilding units with highly reputable yards like Jurong and Samsung is paying off.The combination of a favorable contracting price, good charter agreements and sound newbuilding execution with timely execution will yield significant return to our shareholders."

The contract has been awarded by Elf Petroleum Nigeria Limited (Total), as the Operator of Oil Mining License (OML) 1381 where the Usan field is located. It encompasses the engineering, procurement, construction, installation, pre-commissioning, assistance to commissioning and start-up of the subsea umbilicals (72 km), flowlines (61 km) and risers connecting the 42 subsea wells to the FPSO, along with the oil loading terminal, consisting of an offloading buoy and two offloading lines, and part of the FPSO anchoring system.

Fabrication will be carried out locally in Nigeria, mainly in Saipem’s Rumuolumeni yard. The offshore installation will be carried out by the highly specialised vessels Saipem FDS and Saipem 3000, in water depths ranging from 730 to 850 metres, between the fourth quarter of 2010 and the fourth quarter of 2011.

Prysmian Cables & Systems, a world leading company in the Power and Telecommunication Cables and Systems industry, has been awarded a US$ 18m contract by Brazilian company Petrobras (Petróleo Brasileiro SA) for 35km of static and dynamic Steel Tube Umbilicals to be installed in a number of fields in the Santos, Campos and Espirito Santo Basins, located offshore to the Brazilian coastline. Umbilicals are multifunctional tubing systems which enable sub sea wellheads and manifolds to be connected to platforms or FPSO’s (Floating Production Storage and Offloading). Prysmian designs and produces these products and solutions at its industrial facility in Vila Velha, Brazil.

This contract represents a step forward in reinforcing Prysmian’s positioning in the high value-added market segments of industrial cables for the Oil, Gas & Petrochemical industry, and furthermore consolidates the relationship with its key client Petrobras.

These Umbilicals will form part of the Brazilian State sponsored “Plangas” initiative whereby the Brazilian state controlled company, Petrobras, intends to significantly increase its national daily gas production. The first step of this major project consists of the acceleration and expansion of gas fields already in operational or developmental phases and corresponds to 40% of the additional gas volume forecasted for 2008. The project requires electro-hydraulic umbilicals, in eight different configurations to be installed in nine fields along the Brazilian coast.

The Umbilicals will consist of 9x10,000 psi hydraulic lines, 3x10,000 psi injection lines and four pairs of electrical control cables. This contract will also mark one of the first dynamic production Super Duplex Stainless Steel Tube Umbilicals to be installed by Petrobras in Brazil, which historically has used Thermoplastic hoses. Ranging in water depths of up to 2000m, the umbilicals will be delivered on a fast track basis during 2008, following full qualification testing with the first delivery in mid 2008.

Personnel in Johor perform procurement and customer-service activities, as well as engineering, machining and product assembly. Approximately 100 employees work in the facility today and headcount is expected to exceed 250 by year-end. The Johor facility primarily will supply the company's completion equipment and cementing tools to customers in the Asia Pacific, Middle East, Africa and Europe Eurasia regions.

"We are excited to launch today a greater offering of our products and equipment to our Eastern Hemisphere customers," said David King, president of Halliburton's Completion and Production division. "The addition of the Johor facility is another step in our company's strategic plan to concentrate more of our investments and supply chain resources to our key growth areas."

Len Cooper, Halliburton's senior vice president, Supply Chain and Management Systems, added: "This facility creates a more responsive organization for our international customers while building regional supply networks that support local economies."

"Johor is the economic development hub of Malaysia," said Rao Abdullah, Halliburton's country lead for Central Asia. "Our talented employees here add a strong link in our global supply chain and it is very exciting to network Malaysia into Halliburton's expanding production facilities."

The Shtokman gas field is located in the Barents Sea and is one of the world's largest gas condensate deposits with reserves of approximately 3,800 billion m3 of gas and 37 million tons of hydrocarbon condensate. The onshore facilites for Shtokman Phase 1 will be located at a site adjacent to Teriberka, 120 km east of Murmansk. Phase 1 includes an offshore gas pipeline terminal, a gas treatment plant, a liquefied natural gas (LNG) train with a capacity of 7.5 million tons per year and an export plant for the Russian and European markets.

Technip's operating centers in Paris, France and Saint Petersburg, Russia, will execute the contract. The FEED, which is scheduled to be completed by mid-2009, will form the technical basis for the detailed design, procurement and construction contracts that will be awarded later on. In addition to the FEED contract, Technip has been awarded two additional contracts, one to establish a set of project standards and the second to assist Shtokman with the definition of site preparation works.

For the project, currently planned to be executed over several phases, JPK is providing Front End Engineering Design (FEED) and management of all activities associated with engineering the pipeline. Contracted to provide support throughout all phases of the project, JPK entered phase 1 of the development of the Shtokman natural gas field development in January.

Gerwyn Williams, Managing Director, J P Kenny said, "We are very pleased to have won this contract, which adds to our portfolio of cold region engineering projects. The project comprises a 600km 44” subsea pipeline from the Shtokman field running south to Murmansk. We will be executing the work in our London and Norwegian offices, supported by a Russian contractor, and we'll also be strengthening our presence in Russia by establishing a JPK office in St Petersburg, managed by Russian engineers.”

He added, “As the industry moves into deeper water and more remote environments, we can apply our subsea engineering capabilities to help our clients commercialise the breakthrough technologies needed to economically develop these new discoveries.”

For the technically challenging Shtokman project, which lies in arctic waters beyond the reach of divers, JPK will be delivering its tried and tested solutions to deepwater pipeline installation and will also be responsible for managing an extensive range of interfaces in terms of procurement, planning and compliance with Russian regulations.

These reserve additions came from various sources including the Williston Basin acquisition, enhanced oil recovery operations in North Dakota and successful exploratory drilling in the Cinco Terry Field in Crockett County, Texas. The initial shallow exploratory well in the Newporte prospect (E-M Engh #33-4) located in Renville County, North Dakota has been plugged and abandoned. The well was drilled to a depth of approximately 5,100 feet to test the Madison group and was deemed to be non-commercial after logging, coring and formation testing. The shallow horizons imaged from the 3D seismic data and tested in the E-M Engh #33-4 were not the primary target in the Newporte prospect area. The results from the E-M Engh #33-4 do not diminish the prospect potential of the deeper horizons in the Newporte prospect area that include the Winnipegosis, Red River, Winnipeg and Deadwood formations. The first deep exploratory well on the Newporte prospect (Osterberg #10-3) will be drilled to an approximate depth of 10,000 feet to test the Deadwood sandstone. The Company expects to commence drilling operations during second half of April, 2008 subject to the approval by the State of North Dakota of a unit spacing exception permit and the availability of the contracted drilling rig.

The Company also anticipates spudding the E-M Overton 20-10 well in Renville County, North Dakota this week. The Overton 20-10 well is the second well to be drilled in the Kolbo prospect area and is approximately one mile northeast of the initial well that showed excellent reservoir quality rock with good oil shows. The Company in conjunction with Approach Resources has participated in the discovery of the Cinco Terry Field located in Crockett County, Texas. To date, the Company has participated in 22 successful wells out of 24 locations drilled. The field is currently producing approximately 140 barrels of oil equivalent per day net to the Company. Our plan currently provides for one to two rigs drilling in the field on a continuous basis. The Company has participated in 14 successful wells in our Gulf of Mexico partnership with Hall-Houston Exploration. The partnership is currently conducting drilling operations on Matagorda Island 594 # l well. Future plans provide for two development wells to be drilled in 2008. The partnership has 12 exploratory prospects currently in inventory.

Located onshore in Alaska, 40 kilometres Southwest of Prudhoe Bay, the blocks cover an area of approximately 2,000 square kilometres. The exploration campaign is under way with three wells planned for this drilling season (Winter 2007-2008), and additional exploration wells planned for next winter's season as well.

Total will work closely with the operator, to protect the Alaskan environment. A wide range of measures are implemented to preserve the soil, air, water and wildlife. This acquisition illustrates the Group's desire to pursue its growth strategy in exploration areas with high potential.

Corporate strategy continues to focus on the accumulation of proven and proven producing reserves allowing potential investors the leverage of the physical commodity for which its lease acreage controls. Further reserve studies and updated reports of existing paperwork are being compiled and will be available over the next couple of months.

Oil from the field will be produced by using the Mærsk Inspirer jackup rig, while Navion Saga will be used as a storage vessel for further transport.The gas will be sent to the Sleipner A platform for final processing and export.

Recoverable reserves are estimated at 78.6 million barrels of oil and 1.5 billion standard cubic metres of gas. Production is expected to reach plateau production of 50,000 barrels per day by the end of the first quarter of 2009.

StatoilHydro is operator of the field and has assigned the operations activities to Maersk. Maersk Inspirer is the world's largest jackup rig and the only one of its kind used for production purposes on the NCS.Mærsk Inspirer started drilling in the summer of 2007 and has also completed the processing plant during this period.It has been decided to develop the field with eight wells but another five wells are already being planned and matured.

Technip's operating center in Aberdeen (Scotland) will execute the contract.

It covers:

• project management
• assembly and installation of a production pipeline
• a gas lift pipeline
• a water injection pipeline and an oil export pipeline
• installation of a subsea structure
• eight flexible risers(1) and;
• two umbilicals(2), and;
• pre-commissioning
• tie-ins and testing.

Offshore installation is scheduled for the third quarter 2008 using two vessels from Technip's fleet, the Apache and the Wellservicer. The pipelines will be welded at the Group's spoolbase in Evanton, Scotland.

In the short time since our beginning we have concluded a technology share agreement with Petrowell Limited of Aberdeen, with whom we will initially share this facility. Additionally we have signed an agreement covering the design, manufacture, distribution, service and maintenance of a range of RFID operated wellbore clean up tools.

This multi million dollar deal, signed in January 2008, and with the industry's Houston based field leader is a major step in i³TEC's development. I felt it important that i³TEC demonstrates its commitment to supporting our clients; operator and service industry alike by headquartering part of our operations on their doorstep. RFID has the potential to change the way we view the remote operation of downhole tools, and Houston is and will be one of the hubs of excellence as this technology takes shape."

www.iiitec.com

The increase in oil production offset declines in gas production. As result, revenue increased 9% to $1.3 million. The Company continues to shift its production to take advantage of record high crude oil prices, with more than 77% of Spitfire's production now weighted to oil.

In the third quarter, the Company evaluated a portfolio of assets for acquisition. Spitfire continues to look for assets that offer a predictable production base with a mixture of exploration and development upside. As Spitfire works to identify potential acquisitions, the Company is prepared to add additional engineering, land and exploration talent required to facilitate growth. In the meantime, Spitfire's Saskatchewan production base continues to provide steady cash flow.

The contract is Hallin's largest to date and runs for the next two years with a subsidiary of the Singapore quoted Swiber Holdings Ltd (Swiber). The wholly-owned Swiber subsidiary, Kreuz Offshore Marine Pte (Kreuz). Ltd, will take the Hallin operated Sanko Angel, fitted with one of the Company's saturation diving systems, on a fixed and firm charter for two years. The contract, which starts immediately, will initially operate on projects offshore of Indonesia and Malaysia.

Additionally, a technical service agreement has been put in place, whereby Hallin will provide Kreuz with specialist subsea personnel and additional support equipment, which could increase the size of the Company's project scope significantly.

The 76 metre Sanko Angel is a versatile, multi-purpose, offshore subsea operations and support vessel. It can accommodate up to 128 personnel onboard and is fitted with 50T Subsea crane and helicopter-deck. It will be operating in DP2 (dynamic positioning class 2) mode during the construction and subsea projects.

He holds a bachelor's degree in mechanical engineering from the University of Minnesota and a master's degree in business administration from the University of Houston.

Mr. Kruger began his career with Exxon Company U.S.A. in 1981 in Houston, Texas, and in subsequent years he held various engineering, business planning and management assignments. In 1994, Mr. Kruger was appointed production advisor for Exxon Corporation in Irving, Texas, and in 1996 he returned to Houston to become technical manager for Exxon Ventures with responsibility for Russia and the Caspian Sea. In 1999, Mr. Kruger was appointed vice president of ExxonMobil Development Company with responsibility for deepwater oil and gas developments offshore Africa. In 2001, Mr. Kruger transferred to Kuala Lumpur to become chairman and CEO of ExxonMobil Exploration and Production Malaysia.

In 2003, Mr. Kruger returned to Houston to become vice president for Asia Pacific/Middle East, ExxonMobil Production Company and in 2005 became vice president for the United States, ExxonMobil Production Company. Mr. Kruger was appointed executive vice president of ExxonMobil Production Company in 2006.

Mr. Foster, 64, joined Exxon USA in 1965 as an engineer in the Production Department. During his career, he held a number of domestic and international management assignments. Prior to the ExxonMobil merger, these positions included planning manager and production division manager of Exxon USA, production manager responsible for the UK affiliate of Exxon Company International, vice president, production, of Exxon Company International, chairman and CEO of Esso Malaysia, senior vice president, upstream, of Exxon USA and president of Exxon Upstream Development Company.

Subsequent to the ExxonMobil merger, he was appointed president of the ExxonMobil Development Company in December 1999. He was appointed president of ExxonMobil Production Company in October 2004.

A native of Texas, Mr. Foster holds a bachelor's degree in mechanical engineering from Texas A&M University. Mr. Foster is a member of Texas A&M University Board of Regents, the Texas Board of Professional Engineers and the Society of Petroleum Engineers.

Bechtel, in cooperation with ConocoPhillips under the ConocoPhillips-Bechtel Global LNG Collaboration, has been involved in detailed engineering and procurement for the Angola LNG liquefaction train since early 2007. “The first LNG production is slated for early 2012,” says Bechtel Project Director José Ivo.

The plant, adjacent to the town of Soyo, Republic of Angola, will utilize ConocoPhillips' Optimized Cascade(SM) LNG process and will produce LNG; LPGs, such as propane and butane; condensate; and domestic pipeline gas. The Angola LNG project is an integrated gas utilization project encompassing offshore and onshore operations to monetize gas resources from blocks located offshore of Angola.

The project will reduce natural gas flaring and greenhouse gas emissions from offshore oil producing areas, facilitate continued offshore oil field development, and contribute to the development of a future natural gas-based industry within Angola. Bechtel's engineering, procurement, and construction contract covers the onshore portion of this project.

The two stakes owned through Shell Nigeria Exploration and Production Co. Ltd. are in deep water blocks OML-125 and OML-134, the latter formerly known as OPL-211. Agip, a unit of Eni, owns the remaining 50.2% in each block.

OML-125 currently produces 18,000 barrels a day of oil from the Abo field combined with near term production growth and high potential exploration acreage to complement Oando's existing upstream position. OML-134 although still in exploration phase, has already recorded significant discoveries.

The consideration payable is US$625.7m in cash which will be settled in two tranches. An immediate payment of 10% was paid on Friday, 22nd February whilst the balance will be paid on completion. The consideration and any adjustments will be funded from both internal cash resources and from external financing. Standard Chartered, Standard Bank, BNP Paribas and Merrill Lynch are providing financing to Oando for this transaction. Standard Chartered Bank acted as financial Advisors to the transaction.

Wale Tinubu, Group Chief Executive, Oando Plc said, “We are please to have emerged as the preferred bidder in this competitive international bid. This milestone underpins our preparedness and capability to develop a sizeable upstream portfolio.”

“We have been fortunate to be presented with the rare opportunity to acquire a balanced upstream portfolio in our home market in line with our stated principle to acquire proven, active and near term properties. Our ability to marshal substantial resources to win a bid of this magnitude further reinforces our status as sub-Saharan Africa's leading integrated energy group. We are proud of this development and the positive impact on Indigenous corporate Nigeria's profile in the global oil and gas community.”

The sale is subject to approval by the government and waiver of pre-emption rights by Agip.

Under the existing pooling agreement, Blackdog has a 60% working interest and Privco has a 40% working interest in the proposed wells. The final working interest terms are subject to negotiation. Privco has recently drilled a horizontal well immediately adjacent to the Whitebear property that has tested at approximately 150 barrels of light oil per day. The first joint well is anticipated to be drilled post spring breakup in May/June of 2008. Blackdog President David A.

Corcoran comments, “Southeast Saskatchewan has become a very hot area for horizontal drilling given the royalty holiday on up to the first 48,000 barrels of oil per well, the extremely long expected producing life of these wells which can be between 25-40 years, the high prices received for the valuable light oil produced, the easy year round access and the solid infrastructure that is already in place to handle the oil and water from these wells.

We look forward to drilling our first well this spring and pending success from this well additional wells later in the year.” Blackdog also announces that it has cased its farm-in oil well drilled in Pembina, Alberta in December, 2007 as a potential oil well. Testing continues in two zones of interest in the well. Blackdog has now earned a 12% working interest in two sections of land pertaining to the drilling of well. Forward Looking Statements – This press release contains statements about future events that are forward looking nature and, as a result, are subject to certain risks and uncertainties such as changes in plans or occurrence of unexpected events. Actual results may differ from the estimates provided by management.

www.blackdogresources.com

Under the two-year contract, the value of which has not been announced, MMC AMEC will provide project management, engineering and related services for an asset integrity and de-bottlenecking project on the Malampaya gas field in the Philippines and will cover both the field's integrated platform and onshore gas plant. The contract is part of the Malampaya Deep Water Gas to Power development, which is estimated will provide enough gas to generate 30 per cent of the country's electricity until 2022. AMEC has provided support services to Malampaya since 2000.

"We are delighted to continue to provide support to our long-standing customer Shell on this major development," said Tony Cruddas, President of Growth Regions for AMEC's Natural Resources business.

Mr Noorul Khairi, Chief Executive Officer of MMC AMEC, added: "This is the first major contract to be delivered through MMC AMEC, which was set up in September 2007, and is a key milestone in its successful establishment."

Headquartered in Malaysia's capital, Kuala Lumpur, MMC-AMEC specialises in large-scale integrated projects, including deepwater, as well as providing more traditional greenfield and brownfield engineering services for both upstream and downstream sectors of the global oil and gas market.

ExxonMobil submitted the plan to the Alaska Department of Natural Resources. It involves evaluation, delineation and development of Point Thomson reservoirs through a phased approach to fully develop the hydrocarbon resource for the mutual benefit of Alaskans and the unit working interest owners. Production is anticipated to start by year-end 2014.

The project includes an investment of approximately $1.3 billion to commence a multi-year development and delineation drilling program in the 2008-09 winter season and to construct production facilities, pipelines, and support infrastructure.

Under the initial phase, approximately 200 million cubic feet per day of Point Thomson gas is expected to be produced. Approximately 10,000 barrels per day of liquid condensate that is separated from the gas is planned to be delivered for sale through new and existing oil pipelines. The remaining gas will be injected back into the Thomson Sand reservoir to maintain pressure for continued hydrocarbon recovery and for subsequent gas sales.

In addition, engineering work will be completed to provide necessary information that will allow individual Point Thomson Unit owners to participate in an open season for a gas pipeline. Subsequent field development will be determined, which could include expanding the injection capacity, oil production, pursuing gas sales or a combination.

Craig Haymes, Alaska production manager for ExxonMobil, said, "We look forward to working with the State of Alaska to delineate and bring Point Thomson hydrocarbon resources into production. We have completed significant engineering and geoscience work over the past 18 months, focused on reservoir evaluation and development planning. The assessments indicate that a phased development is a prudent approach to maximize the benefits to the State of Alaska and the Point Thomson owners, especially since a gas pipeline is more than a decade away."

Since 1954, ExxonMobil has invested over $20 billion dollars to develop Alaska's petroleum resources. The company's current working interest share of oil production in the state is approximately 140,000 barrels per day.

In addition to ExxonMobil, the other major Point Thomson Unit owners include BP Exploration (Alaska) Inc., Chevron U.S.A. Inc. and ConocoPhillips Alaska Inc.

WellDynamics will install electronic Venturi flowmeters, electronic pressure/temperature gauges in wells with WellDynamics' SmartWell® completions, and additional electronic pressure/temperature gauges in wells where WellDynamics' flowmeters are installed. This frame agreement applies to all previous Hydro assets in the North Sea. WellDynamics was one of three vendors selected to provide services for the entire contract, estimated to be worth 1 billion NOK, including options, over an eight-year period beginning in Q1 2008.

“The three new frame agreements for downhole monitoring help in securing access to a broad range of measurement technologies for use in advanced wells to maintain productivity levels on the Norwegian Continental Shelf in years to come,” said Vidar Skjæveland, Head of Procurement Drilling and Well Services, StatoilHydro. “We believe that they provide an important means for increased recovery of both new and existing wells.”

Under terms of a separate frame agreement, WellDynamics will provide and implement SmartWell® technology in four wells in StatoilHydro's Gjøa field. The contract is estimated to be worth as much as 45 million NOK over six years, beginning in 2009.

StatoilHydro, established in October 2007 as a merger between Norwegian companies Statoil and Norsk Hydro, has a longstanding relationship with WellDynamics. “We are eager to join with StatoilHydro in the expansion of technologies in the North Sea,” said Derek Mathieson, president and CEO, WellDynamics. “Innovation is critical to improving ultimate recovery across the industry, and we look forward to helping StatoilHydro achieve its goals in these exciting new projects.”

WellDynamics' SmartWell® intelligent completion technology includes solutions for flow control, zonal isolation, permanent monitoring and downhole control, as well as digital infrastructure and fiber optic systems.

The Makassar Strait Explorers Consortium (MSEC) comprises Marathon International Petroleum Indonesia Ltd, Anadarko Popodi Ltd, ConocoPhillips (Kuma) Ltd, ENI Bukat Ltd, Statoil Indonesia Karama AS and Talisman (Sageri) Ltd.

The 689-day contract is expected to commence in the fourth quarter of 2009 following the completion of existing contractual commitments in Angola and mobilization to the Makassar Strait, a deepwater province receiving renewed interest as a result of recent leasing activity.

The estimated contract revenues which could be generated over the 689-day contract period are approximately $351 million. Estimated contract revenues represent the maximum amount of revenues that may be earned in the firm contract period, excluding revenues for mobilization and demobilization.

The GSF Explorer is one of 18 Ultra-Deepwater Floaters in the Transocean fleet. Constructed in 1972 and upgraded in 1998, the drillship is capable of working in water depths up to 7,800 feet.

For the three month quarter ended December 31, 2007, EnerJex delivered a 258% increase in quarter to quarter oil and gas revenues – from $418,590 for the three months ended September 30, 2007, to $1,498,202 for the quarter ended December 31, 2007.

In addition, there was a fifty-six-fold increase in the three month oil and gas revenues for the quarter ended December 31, 2007 – from $26,491 for the quarter ended December 31, 2006. For the nine month period ended December 31, 2007, EnerJex reported oil and gas revenues of $1,982,119, as compared to $76,314 for the same quarter in 2006.

The revenue increase for both the third quarter and the nine months ended December 31, 2007 reflects the aggressive implementation of EnerJex's business model, resulting in growth in crude oil production volumes from leases acquired and developed during these periods as well as increased commodity prices. EnerJex began acquiring oil leases in April 2007.

For the three and nine months ended December 31, 2007, net oil sales volumes were 16,854 and 25,674 barrels respectively, compared to zero barrels for those same periods in 2006. The average commodity price received by EnerJex was $88.89 per barrel of oil for the quarter ended, and $77.20 for the nine months ended, December 31, 2007.

Since April of 2007, EnerJex has closed four acquisitions, drilled 90 new wells (with a 98% success rate), and increased its pre-tax PV-10 (present value) of Proved Reserves by more than $30,900,000 or 1.2 million barrels of oil equivalent. EnerJex has also identified more than 400 additional drilling locations on its existing leases.

Based on production levels achieved during the end of the December 31, 2007 quarter, EnerJex became operationally cash-flow positive, on a non-GAAP basis. As a result, EnerJex will continue to pursue its drilling programs using internally generated funds and other capital alternatives.

EnerJex's CEO, Steve Cochennet, stated, “We are extremely pleased with the results of our efforts to-date. With a 98% drilling success rate and the identification of 400 additional drillable locations – plus quickly building to $30.9 million in PV-10 Proved Reserves as well as $17.2 million in Probable Reserves – we are confident that we have tremendous growth potential ahead of us. We look forward to seeing dramatic results in 2008 and beyond.”

"Aker Kvaerner is recognised for its development of innovative deepwater drilling technologies, satisfying the industry's requirements for efficiency, safety and operability. Acquisition of this technology and competence is a strong strategic lever for us going forward", says Mads Andersen, executive vice president in Aker Kvaerner.

First Interactive AS is a software company specialising in 3D visualisation and simulation for the oil & gas sector. First Interactive has headquartered in Stavanger, Norway, with a subsidiary in St. Petersburg, Russia. In 2007, First Interactive realised revenues in excess of NOK 25 million.

First Interactive and the Aker Kvaerner subsidiary Aker Kvaerner MH, are jointly developing applications for 3D visualisation and simulation of offshore drilling operations. A new generation drilling simulator, enabling realistic 3D visualisation and real-time scenario building, is already launched. The simulator will primarily be used for training of rig operators, but also enables significant reduction in commissioning of drilling rigs currently under construction. The two companies are currently developing solutions for real-time, 3D visualisation of drilling operations which will enable onshore support and control of offshore operations. First Interactive's technology and competence can also be applied to other parts of Aker Kvaerner's business such as marine installation, subsea and well services.

"A realistic, real-time visualisation of the drilling operations will enable rig operators to make better and faster decisions. The result is more efficient drilling, and increased rig uptime. In addition this tool enables us to offer superior training facilities for our clients as well as our own employees," says Roald Amundsen, President of Aker Kvaerner MH.

As the world's first self-propelled, 325-foot/100-meter nominal water depth-rated jack-up well intervention vessel, Remedial Offhore's ESV™ design provides a hybrid between a jack-up drilling rig and a marine vessel.

The new ESV concept offers tremendous versatility and operational functionality, ranging from an incorporated electric well workover package to a large open deck for offshore support functions.

Each vessel is uniquely outfitted to provide a stable work environment for deploying today's most advanced well intervention production enhancement technologies. ESV abilities include well workovers, sidetracking, well abandonment, facility upgrades, brownfield rejuvenation projects and small field developments, as well as providing complete services for well intervention.

Each ESV will employ four GE diesels -- one 8-cylinder V228 and three 16 cylinder engines. Two Remedial Offshore ESVs are under construction in China, one at the Yantai Raffles Shipyard Ltd. in Shandong, and the second at the COSCO Shipyard Group's facility in Nantong.

GE has already delivered to the shipyards two 8V228 and six 16V228 engines, manufactured at the company's Grove City facility. “When we set out to find the best fit for the ESV power generation needs, we considered several key points to be critical to our operation. Therefore, the engine manufacturer selected absolutely had to satisfy these requirements, and that's why we chose GE's reliable engines to meet our needs,” said Remedial Offshore Chief Executive Officer Rich Altman.

The GE engines meet Remedial Offshore's design and operational criteria, such as the ability to have sufficient power available with a minimal number of engines in the existing space, while ensuring adequate redundancy.

With over 15,000 engines operating worldwide, working in some of the most challenging environments, GE's engines offered specific maintenance advantages for ESV operations, where an engine might run for extended periods of time under little or no load.

In addition, Remedial Offshore will have access to GE's worldwide parts and service supply network. Finally, each ESV will benefit from the engines' fuel-efficiency and performance that carries U.S. Environmental Protection Agency Tier II emissions compliance certification.

Altman added, “We knew this would not be an easy task to fulfill and stay within a reasonable budget. We are extremely satisfied with having made this decision and we look forward to future opportunities and joint cooperation wth GE. We will definitely draw on our relationship to refine performance and address any future operating environmental regulations hat come our way.”

“We are delighted to work with Remedial Offshore to provide engines for this novel application,” said John Manison, manager of GE Marine, Erie. “We are confident that, coupled with our outstanding service and support network, our engines will reliably meet the operating requirements for this new- generation vessel.”

The new licences cover a total of seven blocks and part-blocks in both the North Sea and the Norwegian Sea. Dana Norway has been appointed as Operator for the licence in which it holds the largest working interest.

Consequently, Dana Norway has now built a significant portfolio offshore Norway. This includes a 45% stake in the producing Jotun Oil Field, operated by ExxonMobil, and interests in a total of 8 licenses on the NCS covering 16 blocks or part blocks.

Dana’s Chief Executive, Tom Cross commented:- “Dana entered Norway in mid 2007 and, in just a short time, we have built a valuable portfolio of assets and opportunities. Our first Norwegian well, late in 2007, resulted in two oil discoveries at Storskrymten and we now look forward to exploring the new licences we have just been awarded.”

The Dana Petroleum group is now producing oil and gas from a total of 30 fields, spanning the UK, Egypt, Norway and the Netherlands. Dana is actively exploring for new oil and gas reserves in each of these countries and expects to drill a total of 17 exploration wells worldwide in 2008. In addition, the Group has exploration programmes underway in other African countries including Mauritania, Senegal and Morocco. Dana is also the largest shareholder in the independent oil company Faroe Petroleum plc, which is producing and developing gas fields in the UK and exploring for oil and gas offshore Norway, the UK, the Faroes and the Netherlands.

Valued at USD 680 million, the contracted EPC work began in November 2007 with a Limited Notice to Proceed. A full Notice to Proceed with the full project scope was provided on 07 February 2008 with a planned completion date of Q2 2011.

"We are excited to move forward on the engineering and construction phase of this Gulf Coast region LNG regasification terminal. Being selected for this project demonstrates the confidence that our customers have in the experience and abilities of the Aker Kvaerner and IHI team," said John Siffert, president of Aker Kvaerner's LNG business. "We are committed to the completion of the project to the satisfaction of our client, in a timely and safe manner."

Aker Kvaerner, Inc., a principal LNG facilities engineering and construction management firm, and IHI Inc., a market leader in the design and manufacturer of LNG storage and processing systems, are the contract parties responsible for delivering the project. Directed from Houston, Texas, design and engineering for the project will involve approximately 125 personnel from the joint venture. In addition, Aker Kvaerner Industrial Constructors, Inc. will employ a peak construction labour force of approximately 650 to complete the project.

The LNG receiving terminal project will consist of two 160,000 m3 full-containment LNG tanks and a vaporization system. Once complete, the facility will process approximately 1.5 billion standard cubic feet of gas per day, providing the Gulf Coast region with much-needed clean burning natural gas. http://www.akerkvaerner.com

The study is being jointly acquired with Libyan partners AGESCO and NAGECO under an agreement with the National Oil Corporation (NOC) of Libya. This milestone program will be acquired in several phases and will eventually provide data over all petroliferous basins in Libya. The initial phase of the program includes over 250,000 kilometers of data to be acquired in a regional grid and will cover all of offshore Libya as well as several onshore basins. Multiple aircraft will be used simultaneously to acquire the data quickly and efficiently. Data acquisition and processing of the initial phase of the program is expected to take approximately six months. View map.

Upon completion, the aeromagnetic data and interpretation will be used by oil companies for the geological evaluation of new areas for bid rounds and for complementing ongoing work programs in licensed concessions. The data will also be used by NOC for research programs.

The resort’s first filling station, for fuel company Al Maha, was originally planned to have fully buried fuel storage tanks, but due to the presence of a very high water table, the three 50,000 litre tanks are only semi-buried. This means fuel is pumped into the tanks using a positive displacement pump. The site has three multi-product dispensers and is fitted throughout with UPP Extra pipework and PetroTite containment products.

UPP is an ideal choice for locations where protection of the environment is important. At the heart of the UPP system is a highly efficient electrofusion welding system, which connects pipe and fittings to create a seamless direct burial pipe-work system that is also corrosion-free. Full details of the UPP system is at www.petrotechnik.com

The Cameron SaD Phase 1 program will cover a 100 OCS block area that contains several producing fields as well as expired leaseholds. The water depths in the survey range from 40 meters to over 200 meters. The data will be recorded with 9000 meter offsets and by utilizing the Vector-Seis recording system, full coverage around the numerous surface obstructions will be achievable. The long offsets will allow further illumination of deeper targets in the area while providing more definition to the conventional plays.

The Cameron SaD Phase 1 program will commence in March 2008 and is supported by pre-funding from multiple oil companies. Survey acquisition is expected to last approximately seven months. TGS expects to have data available for the March 2009 lease sale. http://www.tgsnopec.com/

The award marks the eleventh major FPSO design that KBR has been involved with in the past decade. Pazflor’s design is a purpose-built FPSO with a topsides weight of 32,200 metric tons. Total's Angolan subsidiary, Total E&P Angola (TEPA), awarded DSME the engineering, procurement and construction (EPC) contract to construct the vessel's moorings, hull and topsides. It is designed with a processing capacity of 200,000 barrels per day of oil, 150 million cubic feet per day of gas, and a storage capacity of about 1.9 million barrels of crude. Facilities are planned for a 20-year design life, and quarters are provided for 220 operation and maintenance personnel. First oil production on Pazflor is scheduled in 2011.

"The Pazflor FPSO is the fourth consecutive mega-topsides and second new-build FPSO awarded to KBR by DSME in the last five years," said John Rose, president, upstream for KBR. "This project builds on KBR's long history of work in Angola and reinforces the importance of this market for our company."

Pazflor includes the Perpetua, Acacia, Zinia and Hortensia fields, which lie in the eastern portion of Block 17 approximately 150 kilometers from the Angolan coast. The FPSO will be spread-moored in a depth of approximately 2500 feet atop 25 subsea oil wells, 2 gas injection wells and 22 water injection wells. DSME will construct the vessel at its fabrication yard in South Korea - For more information,