Eni has started production of the giant gas field Perla, located in the Gulf of Venezuela in the Cardón IV Block. Perla is the largest offshore gas field discovered to date in Latin America and the first gas field to be brought to production offshore Venezuela.
Eni has started production of the giant gas field Perla, located in the Gulf of Venezuela, 50 kilometers offshore. The first production well has been opened and is currently in the clean-up phase.
The field is located in the Cardón IV Block operated by "Cardón IV S.A.", a company jointly owned by Eni (50%) and Repsol (50%). Perla is the largest offshore gas field discovered to date in Latin America and the first gas field to be brought to production offshore Venezuela. This was achieved through close and successful cooperation between the Venezuelan Ministry of Petroleum and Mining, PDVSA, Cardón IV and its Shareholders.
Image courtesy: Repsol
Perla currently holds 17 trillion cubic feet (Tcf) of gas in place, which corresponds to 3.1 billion of barrels of oil equivalent (boe), with additional potential. The reservoir consists of Mio-Oligocene age carbonates with excellent characteristics, located at approximately 3,000 meters below sea level, at a water depth of 60 meters. The best wells are estimated to produce over 150 million standard cubic feet per day (Mscfd) each.
The development of Perla has been planned in three phases to optimize time to market and investment pace: Phase 1 (Early Production) has a production plateau of about 450 Mscfd (corresponding to approx. 40,000 boed net to Eni) increased from the 300 Mscfd initially planned, Phase 2 has a plateau of 800 Mscfd from 2017 (corresponding to approx. 73,000 boed net to Eni) and Phase 3 has a plateau of 1,200 Mscfd from 2020 (corresponding to approx. 110,000 boed net to Eni).
Eni CEO, Claudio Descalzi, commented: "Eni has reached another milestone with the production start-up of the Perla offshore field, in line with the timing presented to the market in March during the Strategy presentation. Perla was for Eni one of the most significant start-up projects of 2015, and the today result confirms the validity of our development model that allowed us to reach production in an industry-leading time to market".
The development plan includes four light offshore platforms linked by a 30‘ pipeline to a Central Processing Facility (CPF) located onshore at Punto Fijo (Paraguaná Peninsula) and 21 producer wells. In the CPF two treatment trains have been installed with the capability of handling 150 Mscfd and 300 Mscfd each.
The development of the field, discovered in late 2009, was completed in 5 years, an industry-leading time to market. This excellent performance was achieved thanks to an extensive use of pre-pack modules in the realization of the onshore gas treatment trains, in order to minimize construction works.
Cardón IV signed a Gas Sales Agreement with PDVSA for all three phases, until 2036. The gas will be mainly used by PDVSA for the domestic market.
Eni’s other operations in Venezuela include the Junín-5 heavy oil block (PDVSA 60%, Eni 40%), located in the Orinoco Oil Belt, which holds 35 billion barrels of certified oil in place. Junín-5 production started in March 2013. In addition, Eni holds a 26% stake in PetroSucre, the operating company which operates the offshore Corocoro oil field, (PDVSA holds the remaining 74%). Eni’s current net production in Venezuela is approximately 12,000 boed and is expected to exceed 50,000 boed by year end, mainly due to the increase in production from Perla.
Subsea 7 has announced the award of four contracts by Chevron Australia Pty Ltd ('Chevron') and INPEX Operations Australia Pty Ltd ('INPEX' - as operator of the Ichthys LNG Project), for the engineering, procurement and construction of an Emergency Pipeline Repair System (EPRS) to be used offshore Australia.
This EPRS project consists of developing a process of repair, including both equipment and contingency procedures, to support the Chevron-operated pipelines and INPEX's Ichthys pipeline off the North and Northwest coasts of Australia. These pipelines are located in various water depths of up to 1,350 meters and are up to 44" in diameter. The contracts comprise design, fabrication and procurement of repair equipment and development of repair methodologies and procedures that will be available during the life of the Chevron and INPEX operated assets.
Project management, engineering and procurement will commence immediately from Subsea 7's office in Perth, Australia, with support from Subsea 7's intervention and autonomous system specialists in Aberdeen. Site integration testing is due to be completed by 2017.
Stephen Steele, Vice President, Life of Field, said: "This award reinforces our position at the forefront of intervention and repair technologies and showcases one of Subsea 7's key capabilities in the area of Life of Field services. We look forward to continuing our relationship with both companies."
Left to right – Michael Scott (Business Development Manager), Donna Stewart (Internal Sales Manager), Anand Puthran (Managing Director), Ian Allan (Global Product Manager)
EFC Group, a leading designer and manufacturer of instrumentation, monitoring, handling and control systems for the global oil and gas industry, is proud to announce that it has won the ‘Business Success Over Three Years’ category at the Elevator Awards 2015.
Previously entitled The Grampian Awards for Business Excellence, the Elevator Awards were relaunched this year. Winners were announced at a black tie ceremony at the Mercure Aberdeen Ardoe House Hotel and Spa on Thursday, 25 June 2015.
The award win comes in recognition of EFC Group’s strong growth and record sales figures over nearly three decades of business. In February, the Group announced that it was one year ahead of schedule for reaching its 2016 turnover target of £30million.
CEO of EFC Group, Bob Will, said: “I am delighted that the business achievements of EFC Group have been recognised by the local business community. Our success in this year’s Elevator Awards is directly attributable to the hard work and dedication of the whole EFC team.
“Since the inception of EFC Group, we have experienced significant growth and we have continued to build upon our strong reputation for delivering a high standard of service and product quality. We pride ourselves on offering innovative solutions to the global energy industry and having a personable approach with clients. I see this as the driving force behind our success. I look forward to building on these achievements in the future.”
The Elevator Awards celebrate outstanding achievements by businesses across the North East of Scotland, in categories which include Most Promising New Business, The Grampian Award for Innovation, Emerging Entrepreneur of the Year, and Employer of the Year.
Organiser of the awards, Elevator (previously known as Enterprise North East Trust), is a social enterprise dedicated to supporting the entrepreneurs, business leaders and employees of today and tomorrow by providing expert business advice and teaching entrepreneurship and enterprising behaviour. The Elevator Awards acknowledge entrepreneurial companies and individuals that are capable of leading the future prosperity of Grampian.
CGG vessel utilization for the second quarter 2015:
The vessel availability1 rate was 74%.This compares to a 84% availability rate in the first quarter of 2015 and a 94% rate in the second quarter of 2014.
This vessel availability rate this quarter is the consequence of:
The vessel production2 rate was 94%.This compares to a 92% production rate in the first quarter of 2015 and a 92% rate in the second quarter of 2014.
Fleet allocation update for the second quarter 2015:
During the second quarter of 2015, our vessels were allocated 42% to multi-client programs (vs 52% in Q2 2014 and 35% in Q1 2015).
Fleet coverage for the third and fourth quarter 2015:
Following the recent award of a large project in Latin America occupying two vessels until the end of the year, the fleet coverage as of July 1st stands at 91% in Q3 and 71% in Q4.
- The vessel availability rate, a metric measuring the structural availability of our vessels to meet demand; this metric is related to the entire fleet, and corresponds to the total vessel time reduced by the sum of the standby time, of the shipyard time and the steaming time (the “available time”), all divided by total vessel time;
2 - The vessel production rate, a metric measuring the effective utilization of the vessels once available; this metric is related to the entire fleet, and corresponds to the available time reduced by the operational downtime, all then divided by available time.
Bibby Offshore’s Asian division, Bibby Offshore Singapore (BOS), has expanded its foothold in the Southeast Asian oil and gas sector by securing multimillion dollars (US) worth of contracts in the first half of 2015.
Drawing on its international fleet of subsea support vessels and work class ROVs, the past six months have seen the division being appointed to perform ROV pipeline inspection, remedial and project management work for companies including Moattama Gas Transportation Company (MGTC) offshore Myanmar, and Singapore based Seascape, a Mermaid Subsea Services company.
Most recently, in April 2015 BOS completed work for Indian-based Larsen & Toubro, a major technology, engineering, construction, manufacturing and financial services company that appointed BOS to perform ROV inspection work on its Yetagun D Platform offshore Myanmar. The project involved a cathodic protection survey, anode survey and flooded member inspection in water depths of up to 110meters.
Peter Hughes, Managing Director at BOS, said: “We are committed to supporting the continued development of the region’s energy sector, and provide efficient and successful delivery of subsea projects to the Asia Pacific region and India. We strive to be seen as a leading supplier of specialist ROV equipment, and experienced personnel, and look to further position Bibby Offshore Singapore as the partner of choice.”
Bibby Offshore now employs more than 1,450 people onshore and offshore worldwide, with offices in Aberdeen, Newcastle, Singapore, Trinidad, Houston, and Norway.
Technip Samsung Consortium was awarded two contracts by Shell for the Browse floating liquefied natural gas (FLNG) project in Australia, operated by Woodside(1).
The Browse project covers the realization and installation of three FLNG units to develop the Brecknock, Calliance and Torosa fields in the Browse Basin, 425 kilometers North of Broome, Western Australia. The Browse project will capitalize on Shell's FLNG experience, as well as on Woodside's offshore and subsea development expertise.
The first contract awarded to the Technip Samsung Consortium covers the front-end engineering design (FEED) elements of the Browse FLNG project, taking into account the composition of the gas, local weather conditions and factors specific to each of the three fields. This contract was immediately novated by Shell to Woodside as operator.
The second contract covers the engineering, procurement, construction and installation of the three FLNG units of the Browse project. This contract is subject to the final investment decision from the client at the end of the FEED.
The Browse project will benefit from insights brought together by both Shell and Technip Samsung Consortium from the design and construction of Shell’s Prelude FLNG facility and aims at maximizing the replication of Prelude FLNG for the three FLNG units of the Browse project.
Nicoletta Giadrossi, President Region A(2) of Technip, stated: "We are proud to have been awarded this contract which will associate the know-how and expertise gained on Prelude FLNG by our teams, while reinforcing our partnership with Samsung Heavy Industries." Nello Uccelletti, President Onshore/Offshore of Technip, commented: “While FLNG represents a breakthrough in the industry, Technip’s teams worldwide have played a key role in this technology since its inception by bringing together our unique combination of expertise - not only in floating units, but also in subsea developments and liquefaction facilities. Today, we are glad to continue to strengthen our relationship with Shell and Woodside and confirm our FLNG leadership.”
(1)The Browse Joint Venture participants are Woodside Browse Pty Ltd, Shell Australia Pty Ltd, BP Developments Australia Pty Ltd, Japan Australia LNG (MIMI Browse) Pty Ltd and PetroChina International Investment (Australia) Pty Ltd.
(2)Region A is one of Technip’s regions comprising Western Europe, Africa and India.
NYC-based PIRA Energy Group believes that crude stock draws have already begun and will pick up momentum in the third quarter. In the U.S., crude and products stocks showed builds. In Japan, crude runs fell marginally and imports dropped back such that crude stocks corrected lower. Specifically, PIRA’s analysis of the oil market fundamentals has revealed the following:
World Oil Market Forecast
Wage gains in developed world to drive faster second half global economic growth with Greece risks muted by potential aggressive ECB/Fed action if needed. The worst of oil market imbalance is over with inventory overhang being much less than generally expected. Crude stock draws have already begun and will pick up momentum in the third quarter. Longer-term supply/demand fundamentals are bullish. The United States is becoming a big factor in the NGL market. MENA geopolitical risks to supply remain substantial, and while an Iranian nuclear deal looks more likely than not, oil markets are expected to have to wait until 2016 for more Iranian oil, and by that time it will need it.
Robust U.S. Stock Build
Commercial stocks built this past week, as both crude and products showed builds. This reversed eight consecutive weeks of crude stock draws, but we expect the crude draws to continue next week. Total demand growth remains strong, including gasoline and distillate. We think the April and current weekly reported crude production values are too high, most likely driven by an overstatement of Texas production.
Japanese Crude and Finished Product Stocks Draw
Crude runs fell marginally and imports dropped back such that crude stocks corrected lower. Major product demand performance was much stronger, up nearly 0.5 MMB/D. All the major finished product stocks levels declined. The indicative refining margin remains very good, though softer on the week as all the major cracks gave ground.
Freight Market Outlook
Tanker markets have been counter-seasonally strong in all size groups during May and June. OPEC and Saudi crude production are near record levels, while refiners are reaping stellar margins across the globe and are more than willing to process (and ship) the additional barrels. Unintended floating storage has also provided support as international markets are struggling with surplus barrels. As a containment step while seeking a buyer, these unplaced cargoes are being slowed down while in-transit or delayed upon arrival resulting in substantial opportunity and demurrage costs well in excess of current contango credits. The recent surge in rates is not likely to persist unless floating storage expands further, which is unlikely in PIRA’s view.
U.S. NGL Field Production Soars
U.S. NGL field production has been increasing at accelerating rates. New data from the EIA show that at 3,314 MB/D, April total NGL field production was nearly 14% higher than a year ago. Year-on-year production increases have been running between 13-15% for each month of this year thus far. PIRA had expected to see field production increases begin to abate due to lower drilling and investment activities; however, this has yet to occur in any meaningful way.
Ethanol Prices Increased
Ethanol prices strengthened during the last half of June as stocks drew and the production of blended gasoline hit record levels. Assessments were also supported by rising raw material costs.
U.S. Output and Stocks Lower
U.S. ethanol production dropped to a six-week low 968 MB/D the week ending June 26 as heavy rain and flooding disrupted operations at some Midwestern plants. Inventories have plummeted by nearly 1.2 million barrels over the past two weeks as ethanol-blended gasoline production soared to a near-record 9,106 MB/D last week.
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.
BMT Group, the leading international maritime design, engineering and risk management consultancy, has announced the appointment of Sir John Hood KNZM as Chairman of BMT Group Ltd with effect from 1 October 2015, following the retirement of Dr Neil Cross at the end of BMT’s financial year on 30 September.
Sir John Hood is a non-executive Director of BG Group plc and WPP plc, Chairman of Urenco Ltd (from which he will retire later this year), Matakina Ltd, and Study Group Ltd; President and Chief Executive Officer of the Robertson Foundation; and Chair of the Rhodes Trust and Teach For All. For five years Sir John served as Vice-Chancellor of the University of Oxford and, before that, as Vice-Chancellor of the University of Auckland after a successful career at Fletcher Challenge, New Zealand’s largest industrial conglomerate.
With a Bachelor of Engineering and a PhD in Civil Engineering from the University of Auckland, Sir John was awarded a Rhodes Scholarship to study at the University of Oxford where he read for an MPhil in Management Studies. He was appointed a Knight Companion to the New Zealand Order of Merit in 2014.
Peter French, Chief Executive, BMT Group comments: “We are delighted that Sir John is joining BMT as Chairman in the new financial year. The group will benefit significantly from his wealth of experience of international business and analytical rigour. I am sure that he will bring an original perspective to our business and help us to remain at the forefront of innovation and design in maritime engineering
“I shall, of course, be sad to see the retirement from BMT of our current Chairman, Dr. Neil Cross. Neil has been with BMT for a total of 18 years and has for the last nine years been our Chairman, in which time the Board has implemented strategies that have seen us weather challenging times, nearly double our turnover to £165m and make distributions of £44m to our staff. The Board and the staff of the whole group wish Neil a very happy and long retirement.”
McDermott International, Inc. announced it has been selected by Saudi Aramco as one of the winners of a global competition for a new Long Term Agreement (LTA) for future brownfield work in various fields in offshore Saudi Arabia.
The LTA, which was signed on June 10, 2015, at Saudi Aramco headquarters in Saudi Arabia, establishes the terms and conditions by which McDermott can bid on future engineering, procurement, construction and installation (EPCI) opportunities in various fields in offshore Saudi Arabia.
The signing is the second LTA between McDermott and Saudi Aramco. Currently, McDermott executes work under an existing LTA with Saudi Aramco, which has been in place since June 28, 2007.
“As a long-time partner and service provider, we understand Saudi Aramco’s offshore fields, standards and specifications – and the value that Saudi Aramco places in McDermott’s fully-integrated EPCI solutions,” said Tom Mackie, McDermott’s Vice President, Middle East. “Our close relationship with Saudi Aramco is important and reflects 45 years of operational and technical success, project delivery and execution, and experience in Saudi Aramco’s offshore fields.”
On June 11th, 2015, Fugro’s premier geophysical survey vessel, the Fugro Americas, successfully completed data collection for a geochemical coring campaign in the Caribbean. The project marks the maiden voyage of the new-build vessel.
Mobilisation for the campaign immediately followed the vessel’s departure from the construction shipyard in Louisiana in April. Her stable design and experienced, dedicated crew enabled efficient and intelligent data collection to enhance survey results beyond expectations. The integrated project comprised 141 piston cores and 7 heat flow measurements that yielded over 1,500 biological and geochemical samples. In an article discussing the campaign, Caribbean Port Agencies, Inc. asserted, “It was a very successful project, both for the vessel owner and the oil major that contracted her for the work.”
The Fugro Americas represents a pivotal advancement in multi-purpose geophysical survey operations and, together with Fugro’s comprehensive understanding of the dynamic objectives and constraints of deepwater operations, supports the company’s global commitment to exceeding client expectations.
For more information:
Melissa Wood; Sales & Marketing Manager, Fugro GeoServices, Inc.; e: This email address is being protected from spambots. You need JavaScript enabled to view it.
Petrobras has long been a pioneer in the adoption and deployment of deepwater technology. This has enabled them to build huge reserves of some 16 billion barrels of oil. Converting these reserves to production, however, is another matter and Petrobras has a history of setting ambitious targets, with a poor record of meeting them.
The long delayed ‘2015-2019 Business and Management Plan’ released last week is a reflection of the new reality for Petrobras. With collapsed oil prices and unfavorable exchange rates, Petrobras has slashed their expenditure plans by 40% from the plans announced a year ago. Recognizing the upstream challenges, the company is now allocating 84% of its budget to E&P compared to 70% in the previous plan. The biggest cut goes to their refining and supply sector which has seen its budget reduced by 67% compared to last year’s plan.
Production decline from existing fields is a huge challenge with around 200,000 bpd of capacity eroded each year. Brazil’s huge deepwater potential remains constrained with Petrobras having to revise their production target for 2020, which now forecasts domestic oil output to increase to 2.8 million barrels per day – 40% lower than its projection 12 months ago. Douglas-Westwood predicts that over the forecast period, Brazil will need to drill around 300 development wells in deepwater, in order to sustain and reach its production target. However, of the 29 new rigs being built by the company, many are under threat from either funding problems or yards withdrawing from the contracts. Douglas-Westwood had already taken a conservative position on Brazil and the cut in production target now brings in line Petrobras’ expectations and our own ‘DW D&P’ forecast. The scale and importance of Brazil in the overall offshore sector means that the impact of the latest spending revisions will be felt throughout the oilfield service industry supply-chain.
Mark Adeosun, Douglas-Westwood London, This email address is being protected from spambots. You need JavaScript enabled to view it.
Wild Well Control, Inc., a Superior Energy Services company and a global leader in firefighting and well control, introduces its exclusive well control training certification program designed to meet the ever-changing needs of the industry by offering a complete selection of action-oriented well control training curricula, which includes both team and individual well control simulator exercises. A first in the industry, Wild Well’s well control training certification program can provide, at the student’s / company’s request, a Competency Report based on the individual simulator exercises, which can be forwarded to the company for their internal HR documentation and to identify additional training requirements if needed.
While continuing to offer IADC and IWCF well control certification options, Wild Well enters the certification arena with a strong 40-year history as an industry-recognized leader in global well control operations, engineering and training services. In 2014, Wild Well trained more than 13,000 students at its well control training centers located throughout the US, UK and Middle East.
The Wild Well certification program meets the standards of other well control certification programs yet further enhances its offerings by focusing on job-specific tasks that provide skill-specific competencies through the use of individualized computer simulations, team-based solution development for well control scenarios and student-driven discussions. Moreover, the Wild Well program offers instruction geared toward regional operations, providing a more efficient use of class time. When they successfully complete the program, students earn a two-year well control certificate similar to other well control certification programs. In addition to an adult training methodology for skill evaluation, the Competency Report, which is exclusive to our certification program, provides students with detailed feedback from completed simulator exercises.
Wild Well clients will now have the option of taking well control certification training for driller and supervisor levels under the IADC WellCAP®, IADC WellSHARP™, IWCF or Wild Well program as determined by their specific well control training needs.
Wild Well certification program classes begin July 6. For online registration and a complete listing of upcoming IADC WellCAP, IADC WellSHARP, IWCF and Wild Well certification program training, visit www.wildwell.com.
In the beginning of May, the crew on Maersk Discoverer reached a great milestone when they finalized their latest well two months ahead of time. The well was another East Nile Delta success for BP, discovering 50 m of gas pay in high-quality Oligocene sandstones. On May 5, Maersk Discoverer completed the deepest well ever drilled in Egypt and the longest ever drilled in the Mediterranean Sea. What makes the well an even greater success is that it was drilled in 234 days, which was a staggering 62 days ahead of BP’s AFE target, thus creating a substantial cost saving. “The strong performance is a result of the dedicated use of the ‘Plan Do Study Act’ methodology in the planning and execution of the work. Also, a structured approach to applying lessons learned from the previous wells Geb and Salamat played an important role,” says Rig Leader Allan McColl.
Observation studies optimized operational procedures
Allan McColl also highlights the strong focus on actively using observation studies to optimize operational performance as a key driver in continuously improving the operational procedures. An example of this was how the auxiliary well centre was used as a "test bed" to break the BHA (Bottom Hole Assembly) handling process into small clearly defined optimized steps. Following a micro KPI process there was a forty five minute time saving on the critical path by integrating the lessons learned. This benefit was then applied on subsequent occasion of handling the BHA.
Another great achievement that significantly contributed to beating the AFE target was BOP reliability. Thorough maintenance of the BOP prior to the Atoll well and involvement of BP and Maersk Drilling Technical Authority teams in evaluating equipment risk assessments enabled the team to keep the BOP functioning on the wellhead for no less than 201 days.
A fruitful collaboration with BP
The success on Atoll marks another milestone in the collaboration between BP and Maersk Drilling in Egypt. “After all the effort everyone on the BP/Maersk Drilling team has put into building a strong joint performance culture this was a very well deserved achievement that everyone should be very proud of” says Unit Director Thomas Falk. He continues: “We have shown BP what we mean when we talk about jointly creating value and we look forward to continuing our discussions with BP on how we mutually benefit from this in our drilling contracts.”
What is a bottom hole assembly?
A bottom hole assembly (BHA) is a component of drilling equipment. It is the lower part of the drill string, extending from the bit to the drill pipe. The assembly can consist of drill collars, subs such as stabilizers, reamers, shocks, hole-openers, and the bit sub and bit.
The characteristics of the BHA help to determine the borehole shape, direction and other geometric characteristics.
The BHA is used to help the drilling process; the proper selection of the right BHA go a long way in ensuring high rate of penetration and thus helps drill quickly and efficiently.
Clariant, a world leader in Specialty Chemicals, signed a framework contract with Statoil, representing the Johan Sverdrup partnership, on June 3, 2015 to supply production chemicals and services for the Johan Sverdrup oil field. The contract has a length of eight years with a four-year option, totaling 12 years. The contract’s start-date is July 1, 2015 and has a significant value, including the option period.
“We are excited to expand on our close relationship with Statoil, which has been built over many years. This long-term contract, especially with the highly contested bid process, shows the confidence Statoil has in Clariant’s capabilities to provide supply of innovative chemicals and services to meet their needs,” says Frode Bekkestad, managing director of Clariant Oil Services Scandinavia AS. “We look forward to continuing our partnership with Statoil to provide high quality products, expertise and services for the Johan Sverdrup field.”
The largest offshore oil find in the Norwegian continental shelf in 30 years, the Johan Sverdrup field is estimated to hold between 1.7 billion and 3.0 billion barrels of oil equivalents. It’s expected to produce 550,000 to 650,000 barrels of oil per day when fully developed. Statoil – Stavanger, Norway – has been named the operator for all phases of field production by the Johan Sverdrup partnership, which consists of Statoil, Lundin Norway, Petoro, Det Norske Oljeselskap and Maersk Oil.
“This agreement provides the foundation for a long-term, successful relationship between our organizations, with the goal of delivering enhanced performance over the full term of the contract,” adds Bekkestad. “This will continue to strengthen Clariant Oil Services’ position as a major supplier in the oil production chemicals market in the North Sea.”
De Nora announces the completion of the acquisition of the Water Purification group of Severn Trent Services. The new business line, called De Nora Water Technologies, will be focused on delivering sustainable and innovative water and wastewater technologies for municipal, marine and energy related water treatment applications.
De Nora Water Technologies, together with Ozono Elettronica Internazionale, a global leader in ozone technologies acquired in May, will be integrated into the De Nora business. De Nora customers and partners will now have access to a full range of disinfection solutions for water and wastewater treatment spanning gas feed, chlorine dioxide, ultraviolet, electrolytic and ozone disinfection from the world’s best known brand names such as Capital Controls®, SEACLOR®, ClorTec® and OMNIPURE in addition to the award winning TETRA® and UAT filtration lines.
According to Lawrence Quinn, CEO of De Nora Water Technologies, De Nora Water Technologies now has one of the most complete lines of technological solutions in the industry. The combination of the expertise and solutions will provide for almost any water and wastewater disinfection need, giving us a tremendous competitive advantage in the markets we serve. And our full range of technologies will certainly strengthen our hand when it comes to entering emerging and fast-growing markets such as China, Brazil and India, where the De Nora group is already well established.
The completion of this acquisition, and the creation of the De Nora Water Technologies business line as part of a Group of almost 0.5bn in turnover, represents an exciting time for De Nora. Stated Paola Dellachà, Chief Executive Officer of De Nora, “We are fully committed to leveraging the expertise from De Nora as a technological pioneer and from the Severn Trent Water Purification side as experts in water treatment applications with a strong history of reliable and reputable products, to meet our vision as a world leader in this field.”
Electrolytic technologies for the on-site generation of sodium hypochlorite from seawater or brine, will experience especially big benefits as a result of the new set-up; there will be an even closer collaboration to improve the performance and the competitiveness of SEACLOR, CECHLO®, OMNIPURE, ClorTec, SANILEC® and BALPURE®. The exclusive access to De Nora’s proprietary self-cleaning electrodes for ballast water applications is certainly a unique feature that only De Nora Water Technologies can offer to this growing need of the marine industry said Luca Buonerba, Chief Marketing and Business Development Officer of De Nora.
Xodus Group has been awarded a contract for the vibration assessment and analysis on the oil train piping and structures for Zakum Development Company (ZADCO) at Zirku Island, 140km north-west of Abu Dhabi.
The work, valued at over $600,000, will pull in services from Xodus’ process, piping, instrumentation and structural teams. The 24-week project will include a Front End Engineering Design (FEED) scope of work With its advanced oil and gas installations, Zirku is considered the main industrial base for the processing, storage and export of oil from the Upper Zakum, Umm Al-Dalkh and Satah fields.
Steve Hamilton, Xodus Group’s Managing Director for Middle East and Asia
In recent months, Xodus’ vibration engineering team has also won a number of other contracts in the Middle East.
The company secured a three-year contract to deliver rotating machinery condition monitoring services with rotating machinery vibration analysis and risk management.
Xodus has also been awarded work to investigate two vibration issues on Sulphur Recovery Units in Abu Dhabi. The work will be split into two phases: phase one for the site survey vibration investigation and phase two to engineer solutions to eliminate/reduce the vibration concerns once the root cause has been identified.
Steve Hamilton, Xodus Group’s Managing Director for Middle East and Asia said: “We have made a strong start to the year with these contract awards. The team deserves a lot of credit as these wins have been built on the excellent feedback from previous projects.
“Xodus’ seamless integration of services from exploration through production and development can greatly enhance the quality of what we deliver as well as saving valuable project time and overall costs. Our specialist vibration expertise is ideally suited to the challenges currently facing operators in the region.”
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