Gauthiers', a Lafayette-based supplier of oil and gas industry containers and support equipment, officially opened the doors to its newly relocated and expanded Houma facility with a community crawfish boil on Friday, April 11.

Approximately 200 invited guests dug into more than 1,000 pounds of boiled crawfish, toured the new facility and learned about the company's newest products. By moving to a larger, 6-acre property and constructing a new facility on Highway 182, Gauthiers' will substantially expand its capacity, including $2 million of offshore containers and baskets in addition to its current fleet of offshore rental equipment.

The company has also hired two full-time employees as a result of this growth: Houma natives Kevin Pizzolato and Jamie Usie. "We're responding to the ever-rising demands of the Gulf of Mexico's offshore exploration, drilling and production industries," said Operations Manager Pizzolato. "We have and will continue to invest heavily in equipment to support their efforts to power the country."

Gauthiers' is a family company founded in Lafayette in 1979 that has evolved and grown over the years to include domestic rentals, international and domestic sales of offshore containers, baskets, workshops, storage containers and related equipment. In 2007, the company added a Houma location to allow them better serve customers working in and around southwestern Louisiana and Port Fourchon. The new facility is located at 4768 Highway 182.

Technological development and knowledge sharing are crucial for conducting prudent operations and avoiding adverse environmental impacts in the northern reaches of the Norwegian Continental Shelf.

"The precautionary principle is fundamental now that petroleum activities are advancing further and further north on the Norwegian Continental Shelf", say Ellen Hambro, Director General of the Norwegian Environment Agency, and Anne Myhrvold, Director General of the Petroleum Safety Authority Norway (PSA).

Prevention and emergency preparedness were the topics of the day on Tuesday, 8 April, at "Når ulykker truer", the accident-risk seminar held by the Norwegian Environment Agency and the PSA.

Many challenges ahead
The northern waters over the Norwegian Continental Shelf pose different potential challenges than areas further south.

Low temperatures increase the risk of icing, drift ice and collisions with icebergs. It is dark for half of the year and polar low pressure systems can bring on sudden changes in the weather with driving snow and strong winds.

Distances are also long. Operations in areas without existing infrastructure present logistical difficulties for ordinary transport and for emergency response.

At the same time, the Barents Sea and northern Norwegian Sea are known to be vital feeding, spawning and nesting grounds for many species of fish and birds. The eco-system around the ice edge is especially productive, and the combination of huge biological diversity and high levels of production make these areas extremely valuable.

The responsibility rests with the companies
The role of the Petroleum Safety Authority Norway in the efforts to protect nature and the environment from harm is primarily focused on the preventive aspect – in other words, trying to stop accidents from occurring in the first place.

The Authority's position is clear: petroleum activities must be conducted as safely in the Barents Sea as on the rest of the NCS. In practice, this means that the special natural conditions in the North may require different technical solutions than further south on the Shelf.

"In areas where the current technical solutions are inadequate, the industry itself needs to produce specific recommendations for resolving the difficulties. The responsibility for operating in a prudent manner rests with the companies. The authorities monitor that the companies are properly assuming this responsibility through consents and audits", explains Anne Myhrvold of the PSA.

Is emergency preparedness good enough?
The Norwegian Environment Agency's particular interest is emergency response to acute pollution.

"We have insufficient knowledge about how emergency response measures work in the ice-filled waters in the High North. For example, how do we handle oil spills in the ice? Many experts propose burning as an effective means of removing oil between ice floes, but it is not known how effective this is for larger oil spills", says the Environment Agency's Ellen Hambro.

Another example is using dispersants to combat oil pollution. At present, these have not been sufficiently well tested in Arctic waters.
Normally, the Environment Agency requires industry to use the best available techniques (BAT) for emergency preparedness for acute pollution. But we currently know too little about how these work when oil meets ice.

"There is a need for improvements in technology and know-how for emergency preparedness in ice-filled waters. This is an urgent issue since we are already having to deal with applications for exploration drilling for oil operations on the ice edge. The oil industry has a responsibility for providing us with the basis we need to be able to regulate petroleum activities", says Hambro.

Knowledge-sharing
The key message to the industry from the Norwegian Environment Agency and the Petroleum Safety Authority Norway is to think cooperatively and holistically.

A number of the operators and rig companies in Norway have experience of high-latitude and Arctic petroleum activities in other countries. This knowledge now needs to be placed on the table, shared and systematised.

"For example, in exploration drilling, it will be advantageous to have several rigs in operation at the same time. This allows more resources to be on hand if something goes wrong", say Myhrvold and Hambro.

Shared understanding
Oil extraction is important for Norway and has broad acceptance in society. But the activity entails a risk of serious harm to the environment and natural resources.

It is important to reduce this risk as much as possible. Stringent requirements from the Environment Agency and the Petroleum Safety Authority will not solve all the problems. The oil companies need to assume their share of the responsibility. This requires cooperation and a shared understanding of which are the most important challenges.

"Precaution is the main principle underpinning our administrative activities. The industry needs to be able to say the same", is the view of the two agencies.

- Relocates its Norwegian oil & gas HQ to Stavanger, led by Marianne Hauso -

DNV GL, the leading technical adviser to the oil & gas industry, is relocating its oil & gas head office in Norway from Høvik to Stavanger in order to be even closer to its customers. Local delivery capacity will be expanded in Stavanger and Bergen and operations will continue in Høvik, Sandefjord, Trondheim and Harstad. DNV GL's operations in Norway are led by Regional Manager Marianne Hauso.

"The oil and gas industry is facing rapid changes, increasing costs and growing public scrutiny on its safety and environmental performance. Since the merger of DNV and GL, we have even more experts holding broad insight in all technical areas, which is critical in helping our customers have safe, reliable and efficient projects and operations. So it's very timely to expand our footprint in the West Coast of Norway," said Marianne Hauso, DNV GL Regional Manager, Norway.

"As the industry moves into increasingly challenging environments and the lifespan of mature assets is being extended, technological innovation is increasingly important to grow performance. Technology is clearly a huge enabler for the industry, but the price of getting new technology wrong can be huge. That's why we spend 5% of our revenue on innovation, running joint industry projects, providing technology qualification services and developing the world's most recognised standards."

The office in Stavanger delivers a broad range of services related to all development phases including exploration, development, operation and decommissioning. In these phases DNV GL delivers services and competences within the areas of Inspection and Maintenance management, Asset integrity, Structure integrity, Offshore crane integrity, Safety and Environmental Risk Management, Technology Qualification, Working Environment, Material selection and Pipeline installation.

"We welcome DNV GL's expansion in Stavanger. The company's global presence and technical expertise makes the Stavanger region an ideal location. Stavanger is a great technology city with abundant talent, knowledge and experience and our growth ambitions for the energy capital of Norway and those of DNV GL are well matched," said the Mayor of Stavanger, Christine Sagen Helgø

DNV GL Oil & Gas, Norway in a nutshell:
• Will be headquartered in Stavanger, Western Norway
• Over 800 oil & gas employees in Norway: Stavanger (100), Bergen (90), Trondheim (50), Harstad (10), Sandefjord (20), Høvik (530)
• Plan to increase staff in Western Norway by 10% in 2014
• Deep industry expertise, particularly in challenging operating environments gained from experience working in North Sea and Arctic projects.
• Provides integrated services in technical and marine assurance and advisory, risk management advisory and offshore classification.
• Maintains and further develops its technology edge through launching new Joint Industry Projects (JIPs) in strategic areas

Marianne Hauso took on the role of regional manager in mid-September last year, prior to which she was regional manager for the oil & gas risk management services. Her area of responsibility includes all services provided by DNV GL to the Norwegian oil and gas industry, with the only exception of classification services for mobile offshore units.

Marianne has been with legacy DNV for 18 years; since she graduated from NTH in Trondheim as a Naval architect in 1995. Since then she has held several different positions, starting out as a safety risk management engineer and -consultant, and moved later into different manager positions in Norway.

At 07.25 on 7 April, Statoil and its partners (GDF SUEZ and OMV) started production on the Gudrun oil and gas field in the North Sea.

"Gudrun is the first new Statoil-operated platform to come on stream on the Norwegian continental shelf since 2005. This is a red-letter day for the company," says Arne Sigve Nylund, Statoil's executive vice president for the Development and Production Norway business area.

The new field contributes to important production from the Norwegian shelf. Statoil expects to recover 184 million barrels of oil and gas (oil equivalent) from the field.

"Gudrun illustrates how we can maximize value creation and realize new projects on the Norwegian shelf by combining new field developments with existing pipelines and facilities," says Nylund.

Around 16.5 million man hours have gone into the Gudrun field development, and a significant number of suppliers from many different countries have contributed to this effort.

The Gudrun investment decision was made during the financial crisis. When the plan for development and operation (PDO) was submitted in 2010, Gudrun was Statoil's only mega-project (investments in excess of NOK 12 billion). Now Gudrun is the first in a long line of field developments operated by Statoil:

"We have delivered the Gudrun field on time and below the cost estimate in the PDO. Choosing a global strategy for Gudrun has contributed to reducing the costs," says Margareth Øvrum, head of the Technology, projects and Drilling business area in Statoil.

The Gudrun platform (Photo: Harald Pettersen/Statoil)

Worth the wait

Gudrun was discovered in 1975. This is a high temperature-high pressure field, and the need for new drilling technology was one of the reasons why these reserves were left in the bank for such a long time. Now we also have available capacity in existing facilities and pipelines.

Oil and gas from Gudrun is sent to Sleipner, where it will be processed before the oil is sent on to Kårstø and the gas to Europe, all through existing pipelines tied in to Sleipner. This allows us to benefit from previous investments made on the Norwegian shelf, Nylund explains:

"The Gudrun concept is a win-win situation. By using existing infrastructure, the Gudrun development costs less and Sleipner gains an extra customer. Gudrun's start-up came at the perfect time."

Modifications have also been carried out on Sleipner and at Kårstø as part of the Gudrun project.

First in a row

Gudrun will be operated from Statoil's offices at Vestre Svanholmen in Sandnes, and is the first new field Statoil operates from the Stavanger region since Sleipner in 1993.

"It's good to see a new field joining the old giants - Statfjord, Snorre and Sleipner. Later on, Gina Krog will also come to Operations South. This field will also be tied in to Sleipner - yet another win-win situation," says Nylund.

GUDRUN FACTS
Gudrun is an oil and gas field in the middle of the Norwegian sector of the North Sea (production licence PL025). The field is located about 55 kilometres north of the Sleipner installations.



The licensees in PL025 are Statoil (operator - 51%), GDF SUEZ E&P Norge (25%) and OMV Norge A/S (24%).

Gudrun has a process facility for partial stabilisation of oil and gas. Oil and gas are transported on to the Sleipner A platform.  The oil is routed on to Kårstø, while the gas goes to European markets through the gas pipelines tied in to Sleipner.

 The field will be developed with a production platform with a steel jacket. 

The jacket was built at Kværner Verdal, the living quarters by Apply Leirvik at Stord. Aibel was awarded the contract for constructing the deck, and built two of the modules in Thailand and one in Poland and Haugesund, where the deck was also assembled. The helicopter deck came from China and equipment packages comes from several countries. 

112 kilometers of pipeline have been laid as well as a 55-km power cable on the seabed between Gudrun and Sleipner. 

430,000 meters of cable have been laid, 2,855 valves have been installed on the topsides and the living quarters has 42 cabins. 

The reservoir is located at a depth of 4,200-4,700 metres, and originates from the Jurassic Age. The pressure in the reservoir is about 860 bar and the temperature approaches 150 degrees. 

The platform will produce from seven production wells, including Gudrun Øst, a discovery made after the plan for development and operation of the Gudrun field was submitted.

Shell today announced an exploration discovery offshore Malaysia. The successful ‘Rosmari-1’ well is located 135 kilometers offshore in Block SK318, and was drilled to a total depth of 2,123 meters.


The well encountered more than 450 meters of gas column. With further exploration planned, the finding is a positive indicator of the gas potential in an area of strategic interest for Shell.

“Rosmari-1 is a testament to our ability to successfully drill and build understanding of new geology within our existing exploration heartlands, adding value to our existing assets in Malaysia,” said Andy Brown, Director Shell Upstream International. “We are expanding and rejuvenating heartlands across our exploration portfolio, including in Brunei, Australia and the Gulf of Mexico.”

“This adds to Shell’s sequence of recent exploration successes in Malaysia, with these discoveries expanding the company’s heartlands positions,” said Iain Lo, Chairman Shell Malaysia.  

Block SK318 is Shell operated with an 85% interest, with the remaining 15% held by PETRONAS Carigali Sdn Bhd.

Tug Fairmount Sherpa has towed rig Sevan Louisiana safely from Singapore to Curaçao. During the 11,500 miles voyage via Cape of Good Hope, stops were made in Port Louis (Mauritius), Walvis Bay (Namibia) and Port of Spain (Trinidad) to take bunkers and for crew changes.

The Sevan Louisiana is a so called Ultra Deep Water rig (UDW), built in 2013 at the Cosco shipyard in Nantong, China, for UK-based Seadrill Ltd. The self-propelled rig, equipped with eight thrusters, can accommodate up to 150 crew members.

After arrival in Curaçao the Fairmount Sherpa performed multiple cargo runs for the Sevan Louisiana. The rig will leave Curaçao on her own thrusters for her next job in the Gulf of Mexico.

Fairmount Marine is a marine contractor for ocean towage and heavy lift transportation, headquartered in Rotterdam, the Netherlands.

Fairmount's fleet of tugs consists of five modern super tugs of 205 tons bollard pull each. Fairmount Marine is part of Royal Boskalis Westminster.

Boskalis is a leading global marine and dredging contractor. With a versatile fleet of 1,000 units Boskalis operates in around 75 countries across six continents with 11,000 employees.

Hoover Container Solutions ("Hoover" or the "Company"), a subsidiary of Hoover Group, Inc., has acquired Dolphin Energy Equipment LLC ("Dolphin"), a leading provider of cargo and waste management rental equipment and related consumables in the Gulf of Mexico region.

Headquartered in New Iberia, La., with a distribution and service center in Port Fourchon, La., Dolphin's assets include a diversified fleet of cargo carrying units ("CCUs") certified to the highest standards including DNV and API regulations. Dolphin is best known for its offshore baskets, trash compactors, food disposal units, pipe slings and related consumables and services.

The combined company will be a premier supplier of chemical, cargo and waste management tanks, baskets, containers and related accessories and services in the global energy marketplace. The acquisition of Dolphin complements the acquisition of Consult Supply A/S which was completed in 2012. Based in Stavanger, Norway, Consult Supply (soon to be Hoover Norway) provides an extensive range of products in the North Sea market including chemical tanks, cutting boxes, baskets and specialized workshops and containers all certified to DNV 2.7-1 standards.

As leaders in the Gulf of Mexico, the combined Hoover-Dolphin team will continue to provide a diverse product range and robust customer services to its customers across the region. Hoover will now provide its customer base with a full range of products including tote tanks (IBCs), offshore chemical tanks, transport frames and bottle racks, ISO Tanks, standard and specialized baskets, cutting boxes and waste skips, dry goods containers, slings, trash compactors, food disposal units and various other related products and services including tank cleaning, technology and transportation.

Hoover's Chief Executive Officer, Donald Young said, "With operations in Louisiana, Houston, Norway, Australia, Brazil, Malaysia and Abu Dhabi the Hoover footprint now covers nearly all the major oil and gas regions around the world. The combined Hoover-Dolphin fleet is one of the largest in the Gulf of Mexico region and makes Hoover one of the only worldwide companies to offer a full range of cargo carrying units including chemical, cargo and waste management products to the Gulf of Mexico market. This acquisition puts us in a stronger position to leverage the upturn in the offshore industry."

"The combination of Hoover and Dolphin will allow us to provide a more complete product and service offering to our customers." said Chad Vidrine, President of Dolphin Energy Equipment. "We are excited to work with the Hoover team because both teams share a similar commitment to high quality products and superior customer service."

MANAGEMENT TEAM
Donald Young, Chairman and Chief Executive Officer and Paul Lewis, President and Chief Operating Officer, of Hoover will continue in their roles in the combined entity. Chad Vidrine, President of Dolphin, will become General Manager of Hoover's new subsidiary, Hoover Offshore, LLC. Robbie Monlezun will continue in his role as Regional Operations Manager of Hoover's new distribution and service center in Scott, Louisiana. As part of the transaction, Cornelius Dupre II, Chairman of Dolphin, will become a shareholder of Hoover Group, Inc. and join the Company's board of directors.

The corporate headquarters of the combined companies will be located in Houston, Texas, with distribution and service centers in Scott, New Iberia and Port Fourchon, La.

T.D. Williamson, Inc. (TDW), a leading supplier of pipeline services and equipment, announced that as a result of a complex subsea pipeline pressure intervention carried out in record time offshore Indonesia, it helped to prevent a major gas supply interruption for millions of residents and businesses in Jakarta.

The operation made company history as the largest subsea pipeline pressure intervention that TDW has ever executed. The challenging hot tap and STOPPLE® plugging operation was carried out for main contractor Timas Suplindo in cooperation with Offshore Construction Specialists on behalf of Pertamina EP, on sections of the pipeline network attached to the Lima Flow Station in the North West Java Sea. Work was carried out as part of the Lima Subsidence Remediation Project. The initiative aims to raise the Lima Flow Station that has been slowly subsiding into the seabed since 1997. The flow station consists of compression, service and process platforms, as well as a platform bridge, flare bridge and tower.

Subsidence remediation works threaten gas supply to Jakarta
Stabilizing the L-PRO platform on the seabed by lifting and consolidating it made it necessary to shut down several lines connected to it. A complete shutdown would have severely disrupted the flow of natural gas from the Lima field. "Nine million live in Jakarta; half of whom rely upon natural gas supplied from Lima field, so the stakes were extraordinarily high," said Edward Sinaga, Execution Lead for Pertamina EP. "Without gas from Lima field, much of the city would have been thrown into chaos, without power and in some cases, electricity, which was utterly unacceptable. It was critical that supply to the city remain steady while jacking operations took place."

To ensure that production and supply would continue uninterrupted during remediation works, several lines were to be installed to bypass the 14-inch and 20-inch MGL pipelines that extend from the TLA and TLD platforms to the L-PRO platform and the 24-inch MGL pipeline that extends between the L-PRO and Cilamaya, where the pipelines make landfall. Pertamina EP engaged TDW to isolate the affected lines so that temporary bypass lines could be installed through which gas would flow, ensuring uninterrupted supply to Jakarta.

Precise planning + speedy execution produce results
The Lima intervention would prove to be TDW's largest, most demanding subsea hot tap and STOPPLE® plugging operation. The operator afforded TDW only five months to plan, gather resources, and execute this subsea project. Each phase – preparation, engineering assessment, fabrication, simulation, mobilization and execution – had to be carried out to perfection in order to meet the demanding deadline.

To maintain flow and facilitate the installation of the bypass lines, TDW developed a solution that required an intricate series of subsea activities: nine hot taps followed by simultaneously executing STOPPLE® plugging operations in six different locations. Because Pertamina EP required that all intervention work be completed within three months, TDW quickly mobilized equipment from North America, Europe and Asia Pacific, accompanied by a team of experienced technicians, to the hot tap and STOPPLE® plugging operation site.

Following the installation and commissioning of the temporary bypass lines upon the successful completion of nine hot taps, the TDW team could commence with setting the STOPPLE® plugs in six different locations. Working from the dive support vessels (DSVs) at depths up to 131 ft. (40 meters), the five-member team used a full complement of specialist machines to hot tap the pipelines, and STOPPLE® plugging systems with Lock-O-Ring® Plus fittings to plug them for final completion. Once the line has been safely isolated, cold-cutting of the isolated pipeline for the installation of sub-sea in-line ball valve commenced. In just 25 days, all of the lines were hot tapped, STOPPLE plugs set and successfully isolated, making it the fastest such operation in TDW history.

For 22 days, the lines remained safely isolated at a pipeline pressure of 13.78 bar (200 psig). The entire operation was completed in just 63 days, from late July through September 2013. Natural gas flowed continuously through the temporary bypass lines to Jakarta, allowing the city to function without missing a beat.

"The sheer scale and complexity of this subsea operation posed many challenges for Pertamina EP, so we are very pleased that it was completed so quickly and effectively," said Edmund Ang, Operations Manager – Asia Pacific for TDW. "The fact that we were able to simultaneously carry out six STOPPLE® plugging operations at different subsea locations meant that every step of the process had to be precisely orchestrated. But our efforts paid off. By completing them in a matter of days instead of weeks, the lines were properly isolated in time for Pertamina EP to divert flow through the temporary bypass lines to Jakarta."

"The success of this operation on Lima field underscores the trust that Pertamina EP places in TDW to deliver critical pipeline intervention services, reliably and professionally," said Sinaga.

ConocoPhillips (NYSE: COP) has announced that the company has donated $1 million toward building a new home for Oklahoma State University's Spears School of Business. In appreciation for this gift, OSU is naming the building's social and collaborative area the ConocoPhillips Student Lounge.

This contribution is in addition to ConocoPhillips' ongoing annual support for scholarships, programs, faculty and facilities across the OSU system.

"Oklahoma State University is grateful for the continuing support of ConocoPhillips and its employees, including many OSU graduates," OSU President Burns Hargis said. "ConocoPhillips is OSU's largest corporate donor, giving nearly $40 million through the years along with hiring countless alumni. ConocoPhillips is an Oklahoma business pioneer and leader, so we are delighted and grateful the company is helping build the new home for our business school."

The new building will serve as the eastern anchor of the university's main quad. It will significantly increase the space for Spears School of Business' 5,000 students and faculty members, becoming a magnet for attracting the region's best minds to engage in dialogue about business, entrepreneurship, economics, law and policy issues.

The ConocoPhillips Student Lounge will be a gathering place for undergraduate and graduate students, providing a central and dynamic location for collaboration, studying and relaxation between classes. The space will be filled with natural light and include ample comfortable seating, computers, study tables and entertainment options to accommodate the needs and desires of today's busy students. Students will also help in the design process to ensure it is the most inviting and visible space for their peers.

"Oklahoma State University continues to provide ConocoPhillips with top talent," said Ken Seaman, ConocoPhillips' executive sponsor for OSU and a university alum. "We're proud to continue to support the university and the Spears School of Business through this investment."
Seaman, an assistant controller with ConocoPhillips, presented the $1 million check to OSU's Dr. Ken Eastman, interim dean and associate professor of management, Spears School of Business, during a special ceremony this morning on ConocoPhillips' downtown campus in Bartlesville, Okla.

"We are proud of the relationship we have forged with ConocoPhillips and are humbled by this gift to our new business building," says Eastman. "The Student Lounge is a perfect way to honor the many Spears School graduates that ConocoPhillips has hired over the years. We look forward to continuing our partnership with ConocoPhillips so that more of our students can build great careers there."

For more information on the nationally acclaimed Spears School of Business and its progress on the state-of-the-art new facility, visit spears.okstate.edu.

NYC-based PIRA Energy Group believes that Asian oil markets remain supported. In the U.S., stocks built.  In Japan, consumption tax increase depresses product demands. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:

Asian Oil Markets Remain Supported

Oil prices should find increasing support moving forward as the worst of the spring crude stock building is almost behind us. Asian gasoline cracks should improve seasonally. Gasoil cracks should hold up with ongoing turnarounds and then higher demand, especially into 3Q.

Consumption Tax Increase Depresses Japanese Product Demands

Total commercial stocks rose 4.6 MMBbls due to a 4.9 MMBbl build in crude. Finished product stocks were modestly lower. Gasoil stocks drew for the eleventh straight week. All the major product demands fell back, as an increase in the consumption tax went into effect April 1st. That increase is likely to keep demands abnormally soft for the next couple of weeks and produce adverse demand comparisons to last April.

A Closer Look at Canadian Shale Liquids Potential

It is becoming increasingly likely that the next location of significant shale liquids growth will be Western Canada. A closer look at resource potential suggests that production volumes will substantially grow. There will be obstacles including cost pressures, water management, takeaway infrastructure limits and environmental concerns that will slow progress but none of these appear to be showstoppers.

Propane Stock Building Has Commenced

U.S. stock building occurred at a faster pace than last season, but propane inventory comparisons will remain far lower year-on-year. Propane exports will grow during the course of the year as new terminal capacity is added. Near term ethane usage is affected by a relatively high level of cracker downtime. The key development is the sharp escalation in spot international freight costs which is adversely impacting trade economics.

Ethanol Prices Plummet

U.S. ethanol prices tumbled the week ending April 4 as plant output increased sharply, enabling stocks to build for the second consecutive week. At the same time, prices had reached a high enough premium over gasoline that companies reduced the percentage of ethanol-blended fuel to the lowest level in about eight weeks.

The information above is part of PIRA Energy Group's weekly Energy Market Recap, which alerts readers to PIRA’s current analysis of energy markets around the world as well as the key economic and political factors driving those markets.

Driven by a major strategic expansion of its operations in Singapore, the MacArtney Group is significantly growing its presence and activities in all Asian markets for underwater technology.

Over the next few months, MacArtney Singapore is securing several new staff members, implementing a major expansion of stock and workshop facilities and opening a dedicated slip ring repair and service center. What is more, the MacArtney Singapore operations will be streamlined to provide direct local access to global MacArtney support for all Asian and Asia Pacific markets.

MacArtney in Asia
With experienced and long standing MacArtney sales professional, Steen Frejo, at the helm as Managing Director, the MacArtney Singapore area of operation has expanded to encompass the entire Asian and Asia Pacific region including major markets such China, Japan, South Korea, Taiwan and support for MacArtney's Australia based office.

In addition, MacArtney Singapore will actively manage the coordination of the entire Asian representative network. Empowered by local market expertise and access to clients, these MacArtney representatives comprise an invaluable asset to the regional success of MacArtney products and systems.

With the expanded MacArtney Singapore operations, MacArtney is able work even closer with its regional representative network which will also benefit from direct access to the Singapore based stock of MacArtney and SubConn® products.

Demand for local supply with global support
To local offshore oil and gas, marine renewable energy, oceanographic and defence industries, the expansion of MacArtney Singapore will mean shorter lead times and better local service for underwater technology systems and products. Further adding to the list of the advantages, direct MacArtney technical support is enabled through the limitation of time zone differences - and with local language proficient sales and technical staff in place at the Singapore office, MacArtney clients and representatives alike will have access to Asian as well as English language support. "The expansion of MacArtney Singapore will definitely bring us much closer to our Asian customers than what has been possible so far", says Steen Frejo and continues: "What started as a one-man regional sales outpost, has now become a fully fledged MacArtney location with local access to global support".

A good start
Since the official opening one year ago, MacArtney has received a warm welcome by all Asia Pacific marine technology markets and segments. Spearheaded by a surging interest in integrated MacArtney system solutions, this development is present across the entire MacArtney portfolio. A good example is the Asia based demand for MacArtney winch and handling solutions which has recently seen a MERMAC S winch system delivered to a defence client in Taiwan, a powerful Active Heave Compensation MERMAC R winch ordered by a Chinese scientific institute and a complete MERMAC research vessel winch solution ordered by a Japanese oceanographic institute.

• New, Flexible, Multi-Role Dnv1a1 Wind Farm Service Code R1 classed offshore support vessel available for a range of operation and maintenance applications up to 150 nautical miles offshore

• State-of-the-art SMV 24 vessel, provides cost-effective, high performance and application flexibility

• Available as a fully managed solution backed by the operational experience and expertise of the UK's leading marine service company• Provides a platform for a range of specialist marine services including diving, ROV, operations and maintenance, accommodation and ship to turbine (STT™) oil change service

James Fisher Marine Services (JFMS) and Supacat has announced the purchase of the first of type Supacat Multi-purpose Vessel 24 (SMV 24). The investment in the SMV 24 vessel marks JFMS's continued commitment to provide innovative solutions to clients that require high assurance when operating in the marine environments.

The SMV 24 vessel establishes a new benchmark in offshore support craft. With an overall length of 25.7 meters, it is powered by two MAN V12 diesel engines providing a maximum speed of 30 knots and fully loaded range of 675 nautical miles. The vessel is capable of carrying three standard ISO 20ft containers with 30T load, providing extensive and versatile deck space for equipment such as ROVs, specialist diving equipment, accommodation modules, ship to turbine (STT) oil change service and offshore facility maintenance equipment (generators, HPUs, bunkering, workshops, tool stores, service spares).

With the addition of optional high quality SOLAS A60 accommodation modules for 12 passengers and permanent accommodation for crew, the DNV1A1 Wind Farm Service Code R1 classed SMV 24 offers an ideal and highly cost-effective solution for servicing sites that are 150 nautical miles offshore for continuous trips of up to one week's duration. The flexibility and versatility of this new SMV 24 vessel renders it capable of reducing both the number of dedicated use vessels and number of visits to site required simultaneously delivering significant cost reduction and increased operational flexibility.

"We are pleased to be able to offer this highly flexible offshore support vessel, to provide efficient and potentially cost-saving operation and maintenance solutions," commented Andy Nattrass, marine operations project manager for James Fisher Marine Services. "This service is likely to be particularly of interest to the fast-growing offshore wind energy sector, for which we are able to combine it with bespoke innovations such as our 'Ship-to-Turbine™' oil transfer concept, an innovative and cost-effective method of exchanging gearbox and hydraulic oils for offshore wind farms. Whether providing services in marine renewable energy in this way, supporting offshore oil and gas operations, or enabling surveying and diving operations, the new SMV 24 vessel provides a highly flexible, multi-role capability that sets a new benchmark in offshore support."

Nick Ames, Managing Director of Supacat, said, "We are delighted that JFMS has chosen to be the launch customer for our new SMV 24 multi-purpose vessel. To have such a prestigious marine services company purchase the very first SMV 24 speaks volumes for the product and for its future potential in this growing sector. Today's announcement is fantastic news for all at Supacat and we are very much looking forward to securing further SMV 24 orders and continuing to grow our presence in the marine sector. JFMS has clearly recognized the unique, flexible, multi-role offering any operator can benefit from by owning the SMV 24 and we are quite sure that others will be following their lead. This is a most encouraging start to our Marine engineering business".

Jim Hey, Group Business Development Director of James Fisher & Sons commented "The design concept of the SMV24 is unique in being able to carry three containers and 12 passengers to site enabling the vessel to undertake multiple tasks during a single mobilization without the need to return to port at the end of the working day. This role flexibility fits with our strategy to create value for our customers in terms of operational efficiency and cost reduction, complementing the specialist marine activities of the group many of which are based around containerized assets and multi-skilled personnel".

As part of President Obama's all-of-the-above energy strategy to continue to expand safe and responsible domestic energy production, Bureau of Ocean Energy Management (BOEM) Director Tommy P. Beaudreau has announced that the bureau will offer more than 21 million acres offshore Texas for oil and gas exploration and development in a lease sale that will include all available unleased areas in the Western Gulf of Mexico Planning Area.

Proposed Western Gulf of Mexico Lease Sale 238, scheduled to take place in New Orleans, Louisiana, in August of 2014, will be the sixth offshore sale under the Administration's Outer Continental Shelf Oil and Gas Leasing Program for 2012-2017 (Five Year Program). This sale builds on the first five sales in the current Five Year Program, which have offered more than 60 million acres and netted nearly $2.3 billion for American taxpayers.

"The nation's economy and our national security depend heavily on adequate and reliable domestic sources of energy and the Gulf of Mexico continues to be a critical component of the Nation's energy portfolio," said Beaudreau. "This proposed lease sale underscores our commitment to make millions of acres of Federal waters available for safe and responsible exploration and development."

Sale 238 will include approximately 3,992 blocks, covering roughly 21.4 million acres, located from nine to 250 miles offshore, in water depths ranging from 16 to more than 10,975 feet (5 to 3,346 meters). BOEM plans to offer blocks located, or partially located, within the three statute mile U.S. - Mexico Boundary Area subject to the terms of the U.S. - Mexico Transboundary Hydrocarbon Agreement. BOEM estimates the proposed lease sale could result in the production of 116 to 200 million barrels of oil and 538 to 938 billion cubic feet of natural gas.

"As one of the most productive basins in the world, this lease sale is another important step to promoting responsible domestic energy production through the safe, environmentally sound development of the Nation's offshore energy resources," said Beaudreau. "The decision to move forward with this lease sale follows extensive environmental analysis, public input and consideration of the best scientific information available."

The proposed terms of this sale include conditions to ensure both orderly resource development and protection of the human, marine and coastal environments. These include stipulations to protect biologically sensitive resources, mitigate potential adverse effects on protected species and avoid potential conflicts associated with oil and gas development in the region.

BOEM's proposed economic terms include the same range of incentives to encourage diligent development and ensure a fair return to taxpayers as used in previous sales.

The terms and conditions outlined for Sale 238 in the Proposed Notice of Sale are not final. Different terms and conditions may be employed in the Final Notice of Sale which will be published at least 30 days before the sale. All terms and conditions for Western Sale 238 are detailed in the Proposed Notice of Sale information package, which is available at: http://www.boem.gov/Sale-238/. CD's and copies of the maps may be requested from the Gulf of Mexico Region's Public Information Unit at 1201 Elmwood Park Boulevard, New Orleans, LA 70123, or at 800-200-GULF (4853).

The Notice of Availability of the Proposed Notice of Sale is available today for inspection in the Federal Register at: http://www.archives.gov/federal-register/public-inspection/index.html.

Noble Energy, Inc. (NYSE: NBL) has announced that Charles D. Davidson, Chairman and Chief Executive Officer, plans to retire May 1, 2015, and that he will leave the Board of Directors at that time. Mr. Davidson, age 64, has served as Chief Executive Officer and Director since joining the Company in 2000. The Board announced that it will propose the election of David L. Stover as a Director at its April 22, 2014 organizational meeting following the Annual Meeting, and that it intends to appoint Mr. Stover as Chief Executive Officer in October 2014. Mr. Davidson will serve as the Company's Chairman until the 2015 Annual Meeting. Mr. Stover, age 56, currently serves as the Company's President and Chief Operating Officer.

"Noble Energy has an exciting future that has been created over many years by an incredibly deep and talented organization," said Davidson. "I am announcing my plans to retire next year with full confidence that the team led by Dave Stover will successfully deliver our exceptionally strong growth plan over the coming years. Dave has played a key role in Noble Energy's success in recent years and has all the necessary skills to lead the Company to even greater performance in the future. While it will be extremely difficult for me to leave my fellow employees at Noble Energy, I will leave knowing that the time is right and that the Board has thoroughly planned for this leadership transition and succession."

"Under Chuck's leadership Noble Energy has been transformed into a highly successful global exploration and production company," said Michael Cawley, Noble Energy's Lead Independent Director. "He will be greatly missed when he retires, but executive succession planning has been a focus of Noble Energy's Board of Directors for many years. Today's announcement that Dave Stover will become Noble Energy's next CEO reflects the Board's extensive planning and confidence that Dave is the right leader for the future Noble Energy. With implementation of the succession plan stretching over 12 months, we anticipate this to be a smooth and seamless transition."

Mr. Stover was elected President and Chief Operating Officer of Noble Energy in April 2009. Prior to that, he served in several other executive positions following his joining the Company in 2002. Before joining Noble Energy, he was employed by BP America, Inc., Vastar Resources and Atlantic Richfield. He holds a bachelor's degree in petroleum and natural gas engineering from Pennsylvania State University and has approximately 35 years of industry experience.
Noble Energy is a leading independent energy company engaged in worldwide oil and gas exploration and production. The Company has core operations onshore in the U.S., primarily in the DJ Basin and Marcellus Shale, in the deepwater Gulf of Mexico, offshore Eastern Mediterranean, and offshore West Africa. Noble Energy is listed on the New York Stock Exchange and is traded under the ticker symbol NBL.

CSA Ocean Sciences Inc. (CSA) and Seiche Measurements are offering a 5-day Protected Species Observer (PSO) and Passive Acoustic Monitoring (PAM) course for individuals seeking professional certification and training for visual and acoustic monitoring of protected species.  The course offered by the Seiche/CSA team adheres to current Bureau of Ocean Energy Management/Bureau of Safety and Environmental Enforcement (BOEM/BSEE) mitigation requirements and standards. 

This level of rigor was chosen as the training standard because BOEM/BSEE requirements are some of the most stringent and include all forms of mitigation measures that are required globally of the seismic industry.  Thus, the certifications and training achieved by this course can be applied internationally with localized or job-specific modifications.  

Both CSA and Seiche Measurements are recognized training leaders of mitigation and monitoring personnel for the offshore seismic industry and other ocean-resource users.  This teaming aims to address the complex needs and requirements of global regulatory bodies as well as the practical needs of the industry.  While each has conducted PSO and PAM training courses individually, their combined expertise allows trainees to obtain unparalleled hands-on experience from experts in the field.  Uniquely suited for this training, CSA and Seiche Measurement bring together expertise from the UK and the United States to ensure trainees are well prepared and fully qualified to perform a comprehensive suite of seismic mitigation duties throughout the world. 

Seismic observer training is a requirement for many regulatory entities to ensure that all mitigation personnel have received correct information concerning permit requirements and methodologies.  Standardized training ensures that industry-hired mitigation personnel have the required training and certifications to perform these important duties.  While regulations vary throughout the world and vessels may use other best practices in unregulated waters, most seismic mitigation protocols require some variation of key methods that include, at a minimum, a specified monitoring zone, a pre-shooting watch, ramp-up or soft-start monitoring, delays or shutdowns of sound sources for species within a given distance, and standardized recording and reporting.  In many regions, PAM is used to supplement visual observation and species identification.  The calibration and efficacy evaluation of each PAM system is unique to the vessel and operational area.  Therefore, the skills required to conduct valid acoustic monitoring are of great importance for both the industry and affected species. 

The training is conducted in both the classroom and in the field with specific training for real-world troubleshooting.  This extensive and practical effort benefits the trainee as well as the industry by providing mitigation personnel with the most comprehensive training experience available today.  The Seiche/CSA team believes that knowledgeable, prepared, and tested personnel is vital for mitigation requiring visual and acoustic observation offshore and provides for reliable data that are crucial in future rule-making and planning.

The course will be held at the CSA headquarters in Stuart, Florida on 17-21 April 2014, with more courses planned for Brazil, the United Kingdom, and Africa later in the year.  For more information about the course and registration, please contact This email address is being protected from spambots. You need JavaScript enabled to view it. or visit www.csaocean.com.

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DW's new Drilling & Production information service is producing some interesting numbers, not least that meeting future global oil & gas demand will require massive numbers of new development wells to be drilled; in 2014 some 83,000, of which 80,000 will be onshore and 3,000 offshore. However, a forecast 17% increase in oil & gas demand by 2020 means that annual well completions will need to climb 35%; in all an additional 670,000 wells must be drilled by the end of the decade.

Offshore, the developing shallow water gas and highly productive deepwater sectors will offset the effects of an aging shallow water oil sector into the forecast, with total offshore oil & gas production set to rise 22% by 2020. DW expect to see a surge of deepwater well completions in the medium term - reaching 476 by 2018, up from 185 in 2013.

New annual onshore well numbers are set to grow 35% by 2020, as more completions are needed to offset ongoing production decline. Worldwide, more drilling for less oil & gas is a recurring theme; the Middle East will need to achieve more than 30% growth in drilling as the NOCs of KSA, Kuwait, Qatar and UAE start large redevelopments in the near-term – nevertheless, production will rise just 10% due to the maturing of existing fields. It is of note that the well numbers of the national oil companies will surge as the international oil majors endeavor to reign-in their spending.

Greenfield projects (onshore and offshore) in Russia could see production maintained at current levels into the 2020s, though recent diplomatic tensions could affect this considerably. China will invest significantly into output at home and abroad, notably Central Asia, as it looks to satisfy rapidly rising domestic demand.

On a global basis, much of the drilling is due to the continued resurgence of the dominant North American market (which accounted for 62% of worldwide development wells drilled in 2013).

Due to the fundamental importance of development drilling to the industry, we will be starting a new monthly Drilling & Production email service shortly. In the meantime further information can be obtained from: