http://www.euro-petrole.comLes dernières nouvelles du site EuropétrolefrEuropétrole7682http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7682Fri, 24 May 2013 00:00:00 +0100
Block 6 covers 5,549 square kilometres in the Mafia basin offshore Tanzania, with a water depth of 1,800 metres. Block 6 is located approx.170 kilometres north of the Statoil-operated Block 2, where the company in 2012 and 2013 has made three high-impact gas discoveries.

After the farm-in completion, operator Petrobras Tanzania Ltd. will hold a 38% working interest, while the remaining 50% is held by Shell Deepwater Tanzania B.V.

The transaction is subject to approval by Tanzanian authorities.]]>7684http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7684Fri, 24 May 2013 00:00:00 +0100
Esso S.A.F. annonce aujourd'hui que la cession est devenue effective, les conditions suspensives ayant été levées et les autorisations administratives obtenues.

Delek France devient ainsi revendeur à la marque et continue à approvisionner en carburants Esso les stations-service Esso Express de la zone Ouest Atlantique, à travers un contrat d’approvisionnement long terme. Le consommateur pourra toujours utiliser sa carte Esso Card et bénéficier des atouts du concept Esso Express qui sera à présent opéré par Delek sur la zone. La mise en place de cet accord n’a pas d’effet sur les autres activités de la société Esso S.A.F. et cette transaction n’aura pas d’impact matériellement significatif sur les comptes de l’exercice 2013.

Alors que le marché de la distribution de carburants est toujours plus compétitif, Esso S.A.F. estime que ce mode de gestion de stations-service avec Delek France, est le moyen le plus efficace, non seulement de servir ses clients sur la région mais aussi d’assurer sa compétitivité et sa croissance future.

En France, le réseau Esso comprend près de 700 stations-service à la marque Esso dont près de la moitié sont des stations-service automates Esso Express.]]>7680http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7680Fri, 24 May 2013 00:00:00 +0100
The agreement was signed by Rosneft President and Chairman of the Management Board Igor Sechin and Venezuelan Oil Minister and PDVSA president Rafael Ramirez in the presence of the Venezuelan president Nicolas Maduro.

The enterprise's creation was approved by the National Assembly of Venezuela, the President's decree and a resolution by the ministry of oil and mining industry.

Rosneft's stake in the joint venture will amount to 40%, the other 60% will be held by CVP. The Carabobo-2 project includes blocks Carabobo-2 North and Carabobo-4 West with a total area of 342 square kilometers located in the Orinoko river's heavy crude belt. Reserves at the blocks are estimated at 40 billion barrels (6.5 billion tonnes). Commercial oil production is expected to peak at over 400 thousand barrels per day (about 25 million tonnes per year).

According to the memorandum, Rosneft is to pay a bonus of $1.1 billion for entering the project in two tranches (40% and 60%) and also to offer a loan of $1.5 billion to Corporacion Venezolana del Petroleo with the maximum yearly take-off of $0.3 billion.

The joint venture plans to perform the entire cycle of site exploration and development, building ground facilities and field pipelines. There are also plans for building a special refinery (upgrader) to increase the quality of the extracted oil to commercial.

Rosneft’ President said before that the new joint venture would be named Petrovictoria. The companies actively work on other new projects including the Venezuelan shelf, he also added.

The companies have also signed a confidentiality agreement allowing Rosneft to obtain geological data on Venezuelan offshore blocks for possible future cooperation.

Earlier Rosneft and the Venezuelan company had signed a memorandum of intent to study several gas sites on this country’s shelf.On May 23, an agreement to create a joint venture to develop heavy oil reserves in Venezuela in the framework of the Carabobo-2 project was signed in Barcelona, Venezuela, by Rosneft and the Venezuelan Corporacion Venezolana del Petroleo (CVP), a subsidiary of PDVSA.

The agreement was signed by Rosneft President and Chairman of the Management Board Igor Sechin and Venezuelan Oil Minister and PDVSA president Rafael Ramirez in the presence of the Venezuelan president Nicolas Maduro.

The enterprise's creation was approved by the National Assembly of Venezuela, the President's decree and a resolution by the ministry of oil and mining industry.

Rosneft's stake in the joint venture will amount to 40%, the other 60% will be held by CVP. The Carabobo-2 project includes blocks Carabobo-2 North and Carabobo-4 West with a total area of 342 square kilometers located in the Orinoko river's heavy crude belt. Reserves at the blocks are estimated at 40 billion barrels (6.5 billion tonnes). Commercial oil production is expected to peak at over 400 thousand barrels per day (about 25 million tonnes per year).]]>7679http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7679Fri, 24 May 2013 00:00:00 +0100
The resumption of the agreements takes place two days after the ceremony that marked the maiden voyage, in Suape, state of Pernambuco, of the vessel called Zumbi dos Palmares, which EAS delivered to Transpetro.

The Pernambucan shipyard will get technical assistance from Japanese outfit IHI Marine United, which has committed to provide the designs for the 12 vessels for which the agreements had been suspended, as per the specifications set forth under the Purchase and Sale agreement. The designs for the first series of 10 Suezmax ships were provided by Korean company Samsung, which is no longer the yard's technology partner. This led Transpetro, in May 2012, to suspend the 12 orders until EAS submitted a new partner meeting international standards.

Conceived by Transpetro to revitalize the Brazilian shipbuilding industry, Promef envisages the commissioning of 49 vessels from Brazilian shipyards. Of this total, five vessels entered into operation within an 18-month period: The João Cândido and Zumbi dos Palmares Suezmax vessels, built by EAS; and the Celso Furtado, Sérgio Buarque de Holanda, and Rômulo Almeida product ships, commissioned from the Mauá shipyard, in Niterói (RJ). The third of 22 vessels to be delivered by EAS, the Dragão do Mar will be ready late this year.

"The Brazilian shipbuilding industry is gaining traction, overcoming the learning curve at an accelerated rate. In fewer than 18 months, Zumbi dos Palmares is already the fifth vessel delivered. Promef is on track, making a critical contribution to the consolidation of the Brazilian shipbuilding industry, a strategic sector for the country, with great capacity to generate jobs and economic development. Today, Brazil has the third largest order portfolio in the world, and, therefore, it already has sufficient scale to gradually increase its level of productivity and to be internationally competitive," says Transpetro CEO, Sergio Machado]]>7677http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7677Fri, 24 May 2013 00:00:00 +0100
“Despite considerable market changes, increased complexities, current challenges, and new resource opportunities, there is a need to return to industry fundamentals – namely supply, demand, macroeconomic, regulatory, cost price and competitive behaviour factors – in order to understand the future direction of the oil and gas sector,” said Adi Karev, DTTL Global Leader, Oil and Gas.

<strong>Highlights from the report include:</strong>
<strong>Shale gas – A global or regional resource?</strong>
The success of North American shale gas has spurred interest in duplicating the results in other countries. However, according to the report these countries still have a long road ahead before they can begin to see the gas volumes and supporting infrastructure needed to dramatically lower domestic natural gas prices and create export opportunities. Given the greater technical challenge of shale gas and higher development costs, exploitation of shale resources is not easily replicable in other markets. While some countries are making progress, over the next one to three years it will remain a largely regional resource with an uncertain impact on the global market past this timeframe.

<strong>LNG pricing</strong>
The end of oil indexation? Oil indexation will be one of several pricing approaches for LNG long-term contracts in Asia Pacific. As diverse supplies enter the LNG market over the next 12 months through to 2017, the dynamics of supply competition will drive transition away from contracts purely indexed to oil prices and at high oil price parity in the Asia Pacific region. A future mixture of contract pricing approaches: prices set lower from oil price parity, hybrid indexation, and full gas hub indexation.

<strong>Resource nationalism</strong>
Entering a period of low tide? In the short term, resource nationalism will recede as new resource-rich countries seek to attract investment and access technology. Investors and global oil and gas companies view resource nationalism as an unmanageable risk. In the long term, resource nationalism will rise as countries progress through the stages of resource development and gain technological expertise.

<strong>NOCs</strong>
Capturing the playing field NOCs are evolving their global expansion by competing for complex barrels. While the global expansion of NOCs is not a new story, the fact that expansion strategies differ between oil and gas is a recent and important development. NOCs have evolved from players focused on production in domestic oil resources to becoming interested in more complex barrels in unconventional oil, and are also pursuing gas.

<strong>Managing market complexity</strong>
The direction in which U.S. medium-size integrated companies, supermajors, and NOCs have evolved shows that vertical integration, as the winning business model in the oil sector is far from becoming a market certainty. Instead, vertical integration largely depends on aligning company strengths and strategy with local and global market conditions. Deloitte’s analysis indicates that uncertainty is very much the order of the day. How companies react to and deal with this uncertainty is changing the notion of a singular business model and giving rise to different business models.

“The industry has evolved to a point where market complexity is best managed through diversification of companies, partnerships, and flexible business models. As we look towards the next three to five years, what previously seemed more certain will become less so,” said Karev.

“In fact, even the decade's primary game-changer –shale gas – will likely have less of a definitive global impact and become a more regional resource, with certain countries able to export surplus gas via LNG. LNG pricing will become more complex using various pricing models; and the impact of LNG exports on the global market will depend on countries' resource policies, which ebbs and flows as production increases, making NOC and IOC partnerships grow in importance,” he said.

<strong>About Deloitte</strong>
Deloitte refers to one or more of Deloitte Touche Tohmatsu Limited, a UK private company limited by guarantee, and its network of member firms, each of which is a legally separate and independent entity. Please see www.deloitte.com/about for a detailed description of the legal structure of Deloitte Touche Tohmatsu Limited and its member firms.

Deloitte provides audit, tax, consulting, and financial advisory services to public and private clients spanning multiple industries. With a globally connected network of member firms in more than 150 countries, Deloitte brings world-class capabilities and high-quality service to clients, delivering the insights they need to address their most complex business challenges. Deloitte has in the region of 200,000 professionals, all committed to becoming the standard of excellence.]]>7676http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7676Fri, 24 May 2013 00:00:00 +0100
The Karish discovery is the fifth discovered field with an estimated gross mean resource size over 1 Tcf. It is also the seventh consecutive field discovery for Noble Energy and its partners in the Levant Basin. With the addition of Karish and the recent increase in resource estimates at Tamar and Leviathan, total discovered gross mean resources in the Levant Basin are now estimated to be approximately 38 Tcf.

The Ensco 5006 rig drilled the Karish well and will relocate to Cyprus where it is scheduled to spud an appraisal well at the Cyprus A discovery next month.

Noble Energy is the operator of the Alon C license with a 47.06 percent interest. Co-owners are Avner Oil and Delek Drilling each with a 26.47 percent interest.

(1) Range of resource estimate based on 75th and 25th percentile probabilities

<strong>About Noble Energy</strong>
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.]]>7675http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7675Fri, 24 May 2013 00:00:00 +0100
« Aux Etats-Unis, notre stratégie consiste à consolider notre outil industriel en tirant bénéfice des évolutions du marché » commente Patrick Pouyanné, directeur général Raffinage-Chimie de Total. « Le vapocraqueur de Port Arthur est l’un des plus grands craqueurs au monde avec une capacité de production de 1 million de tonnes d’éthylène par an. Il a été mis en service en 2001 pour traiter du naphta, dérivé du pétrole. Compte tenu de la hausse du prix des produits pétroliers d’une part et de l’apparition de ressources gazières abondantes d’autre part, nous l’avons adapté pour le rendre flexible et maintenir ainsi sa compétitivité. Il a désormais accès à de l’éthane d’un coût d’environ 30 $ par baril équivalent pétrole (bep), donc très concurrentiel par rapport à celui du naphta (environ 100 $/bep), mais aussi à des GPL comme le butane et le propane, eux aussi meilleurs marché ».

Le projet permet d’approvisionner le vapocraqueur de Port Arthur en éthane produit sur le site de Mont Belvieu (Texas) où transite la majorité des liquides de gaz américains. Depuis le début du mois d’avril, le vapocraqueur de BTP est désormais en mesure de produire près de 40 % de son éthylène à partir d’éthane et 40 % à partir de butane et de propane. Au-delà de ce projet, BTP a engagé la construction d’un dixième four sur éthane, dont le démarrage est prévu au second trimestre 2014. Il permettra d’améliorer la disponibilité du vapocraqueur et d’augmenter sa capacité de production de près de 15 %, le rendant ainsi encore plus performant.

« Compte tenu de l’impact de cette révolution des gaz de schiste sur la pétrochimie mondiale, Total étudie également un projet de nouveau vapocraqueur sur éthane qui serait couplé au premier vapocraqueur de Port Arthur de façon à maximiser les synergies tout bénéficiant de cette matière première très compétitive » a ajouté Patrick Pouyanné.
Dans le cadre de sa stratégie intégrée, Total destine sa part d’éthylène produite par BTP à son usine de polyéthylène de Bayport (Texas), et sa part de propylène à son usine de La Porte (Texas), la plus grande usine de polypropylène au monde.

<strong>A propos de Total Petrochemicals &amp; Refining USA, Inc. (TPRI)</strong>
Total Petrochemicals &amp; Refining USA, Inc. (TPRI), dont le siège est situé à Houston, fait partie de la branche Raffinage-Chimie de Total S.A. TPRI est un producteur majeur de produits pétroliers, d’oléfines, de styrène ainsi que de polymères tels le polypropylène, le polystyrène, le polyéthylène aux États-Unis. La société emploie plus de 1 600 collaborateurs dans les activités de production et de R&amp;D basées au Texas et en Louisiane. ]]>7674http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7674Thu, 23 May 2013 00:00:00 +0100
Le projet a pour objectif de limiter les risques liés aux torchères dans les installations de gaz offshore associés et de développement de gaz intégré, ainsi que ceux liés à l’exposition aux gaz du personnel durant les opérations et la maintenance de ces unités en cas d’extinction de flamme.

Le contrat comprend :

- le déplacement de la torchère South Relief à l’est de la torchère F-14 existante,
- l’installation de deux nouvelles torchères sur l’emplacement existant de la torchère South Relief,
- la démolition des torchères F-11 et F-14,
- le remplacement d’un bec de torchère,
- une nouvelle sous-station électrique.

Le centre opérationnel de Technip à Abu Dhabi réalisera le contrat qui devrait s’achever au premier semestre 2015.

Vaseem Khan, Senior Vice President de Technip au Moyen-Orient, a déclaré : « Nous sommes ravis d’avoir remporté ce contrat EPC(2) auprès d’ADMA-OPCO. Il confirme la confiance qu’ils portent à notre expertise en conception et construction d’installations complexes, ayant déjà réalisé l’ingénierie d’avant-projet détaillé et l’ingénierie détaillée de certains de leurs projets ».

(1) Abu Dhabi Marine Operating Company.
(2) Ingénierie, fourniture des équipements, construction.

<strong>A propos de Technip</strong>
Technip est un leader mondial du management de projets, de l’ingénierie et de la construction pour l’industrie de l’énergie.

Des développements Subsea les plus profonds aux infrastructures Offshore et Onshore les plus vastes et les plus complexes, nos 36 500 collaborateurs proposent les meilleures solutions et les technologies les plus innovantes pour répondre au défi énergétique mondial.

Implanté dans 48 pays sur tous les continents, Technip dispose d’infrastructures industrielles de pointe et d’une flotte de navires spécialisés dans l’installation de conduites et la construction sous-marine.]]>7673http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7673Thu, 23 May 2013 00:00:00 +0100
Ce contrat porte sur l’ingénierie, l’approvisionnement des équipements et la fabrication d’un four de vaporeformage selon la technologie Haldor Topsoe dans le cadre de la construction d’une unité de production de méthanol au sein d’une usine chimique située à Clear Lake au Texas.

La livraison de ce four est prévue pour novembre 2014.]]>7672http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7672Thu, 23 May 2013 00:00:00 +0100
In keeping with the mid-term investment program, the company plans to commission a light naphtha isomerization unit and a catalytic cracking gasoline hydrotreatment unit in 2013. The second stage of reconstruction of the LCh-24-2000 diesel fuel hydrotreatment unit will also be completed. This will result in the Moscow Oil Refinery converting completely to the production of grade 5 gasoline per the Russian Federation Technical Regulation. The proportion of grade 5 diesel fuel will exceed 75 percent of the total volume of diesel fuel produced at the Moscow Oil Refinery. Next year, the refinery will complete the second stage of reconstruction of the ELOU-AVT-6 crude oil vacuum distillation unit, which will allow it to increase substantially production of high-quality gasoline and diesel fuel.

One of the key measures in the investment program will be construction of a combined oil refining unit with a capacity of 6 million tons per year. The new complex will bring together the production processes of the various components of high-octane gasoline and summer and winter diesel fuel, which are currently performed at three separate units. This large-scale project, which is slated for completion in 2017, seeks to introduce the most advanced technologies at the Moscow Oil Refinery, to raise the enterprise’s operational readiness, to improve industrial safety and the refinery’s environmental indicators.

Construction of a bitumen modification unit designed to produce 60,000 tons of polymer modified bitumens and 7000 tons of bitumen emulsions per year will begin at the Moscow Oil Refinery in 2013. This will help increase the output of bitumen products significantly, in keeping with the highest international quality standards.

The Moscow Oil Refinery is also planning to implement a number of projects aimed at reducing the refinery’s environmental impact and raising its energy efficiency. The sulfur recovery unit, the chemical treatment unit, the CVK central air compressor unit, the VK-3 air compressor unit, and external and internal power supply infrastructure will be reconstructed in 2013. The company plans to introduce a natural gas supply system at the refinery. All of this will help reduce and stabilize the borders of the refinery’s sanitary protection zone and improve environmental conditions in Southeastern Moscow substantially.

<strong>About Gazpromneft Moscow Oil Refinery</strong>
Gazpromneft Moscow Oil Refinery is a subsidiary of Gazprom Neft. The refinery’s capacity is rated at 12.15 million tons per year. The enterprise produces automotive gasoline, diesel, marine fuel, aviation fuel, heavy fuel oil, high-octane additives for automotive gasoline, bitumen, and multipurpose gases. The refinery ranks very high for production of high-octane gasoline and diesel fuel, and provides approximately 40 percent of the petroleum products consumed in the Moscow region.

A large-scale modernization program is underway at the Moscow Oil Refinery, which will involve over 130 billion rubles invested before 2020. The program seeks to improve the quality of petroleum products, increase the oil conversion rate, and raise the enterprise’s production efficiency and environmental friendliness.

<a href="http://www.euro-petrole.com/raffinerie-de-moscou-l-286" target="blank" class="lien">See the site of the Moscow Refinery</a>]]>7671http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7671Thu, 23 May 2013 00:00:00 +0100
Stones is an ultra deepwater project located in the Walker Ridge area of the Gulf of Mexico, approximately 200 miles (322 kilometers) off the Louisiana coast in approximately 9,600 feet (2,926 meters) of water. FMC Technologies' scope of supply includes eight subsea trees, a subsea manifold, topside and subsea controls and associated equipment.

"Deepwater operations in the Gulf of Mexico require advanced capabilities and innovative solutions," said Tore Halvorsen, FMC Technologies' Senior Vice President, Subsea Technologies. "FMC Technologies is pleased to be able to work with Shell to deliver the technologies that they need to develop these fields."

<strong>About FMC Technologies</strong>
FMC Technologies, Inc. (NYSE:FTI) is a leading global provider of technology solutions for the energy industry. Named by FORTUNE® Magazine as the World's Most Admired Oil and Gas Equipment, Service Company in 2012, the Company has approximately 18,900 employees and operates 30 production facilities in 16 countries. FMC Technologies designs, manufactures and services technologically sophisticated systems and products such as subsea production and processing systems, surface wellhead systems, high pressure fluid control equipment, measurement solutions, and marine loading systems for the oil and gas industry.]]>7670http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7670Thu, 23 May 2013 00:00:00 +0100
Lors d’une réunion à Bruxelles, à la veille de la réunion du conseil européen consacrée à l’énergie et à la fraude fiscale le 22 mai 2013, ces huit sociétés énergétiques ont convenu dans une déclaration commune de souligner la gravité des difficultés actuelles auxquelles le secteur doit faire face et de proposer des mesures appropriées. À l’évidence, le manque actuel de visibilité sur les politiques énergétiques et les incertitudes en matière de réglementation entraîneront inévitablement la raréfaction des investissements dans le secteur de l’énergie, avec des retombées négatives sur la sécurité de l’approvisionnement, l’emploi et la relance de l’économie européenne. La poursuite du statu quo n’est tout simplement pas envisageable.

Les signataires restent déterminés à soutenir l’ambition de l’UE de parvenir à une politique énergétique fondée sur les principes de la concurrence, de la sécurité des approvisionnements et du développement durable, et ils adhèrent pleinement à la nécessité de libéraliser les marchés de l’énergie. Nous estimons que chacun de ces éléments est une condition préalable à une politique énergétique concurrentielle pour les clients industriels et les citoyens. Toutefois, la réalité à laquelle chacune des entreprises énergétiques a dû faire face ces dernières années est que l’UE et certaines politiques nationales de l’énergie n’ont pas apporté tous les avantages escomptés. Concrètement, les entreprises européennes du secteur de l’énergie sont au cœur de la tourmente, dans une situation qui d’une part menace la sécurité de l’approvisionnement et la transformation vers une économie à faible émission de carbone et d’autre part compromet leur capacité à attirer les capitaux.

Toutefois, il n’est pas trop tard pour que, à travers une approche redynamisée, l’UE assure aux citoyens européens des prix concurrentiels et un approvisionnement sécurisé de l’énergie. Prises simultanément, ces mesures serviraient à restaurer la confiance des entreprises du secteur de l’énergie dans l’attractivité du marché européen de l’énergie. Il est absolument crucial qu’une telle redynamisation de l’approche de l’UE continue d’appuyer les efforts engagés en matière de changement climatique, et repose sur les nouveaux éléments suivants :

- Une conception du marché améliorée, notamment une approche coordonnée au niveau européen à l’égard de mécanismes de capacité assurant une rémunération équitable de l’ensemble des actifs contribuant à la sécurité de l’approvisionnement des clients européens.
- Un marché européen du carbone qui soit en mesure de soutenir des technologies favorables au climat et à travers lesquelles des perspectives fiables sont apportées, notamment en fixant des objectifs ambitieux mais réalistes en matière d’émission de gaz à effet de serre après 2020.
- Une approche plus durable de la promotion des sources d’énergie renouvelable, afin de réduire les coûts pour les citoyens et de favoriser une plus grande convergence entre les États membres.
- Un renforcement des grands axes d’une politique de déclenchement des investissements dans les technologies prometteuses, telles que le stockage de l’énergie, les nouvelles énergies renouvelables, le captage et le stockage du carbone, les réseaux et compteurs intelligents et le gaz de schiste.

Les dirigeants des huit entreprises du secteur de l’énergie ont de fortes attentes à l’égard des responsables politiques de l’UE, pour que ceux-ci prennent la mesure de la situation critique à laquelle le secteur de l’énergie est confronté. Il appartient également à ces dirigeants de définir de nouvelles orientations de politique publique fondées sur les éléments figurant dans la déclaration commune, axés sur la contribution apportée par les investissements dans le secteur de l’énergie, non seulement par l’approvisionnement sécurisé et efficient des produits, mais également par la création d’emplois et la relance efficace de l’économie.

*Représentant les entreprises du secteur de l’énergie suivantes : ENEL, GASTERRA, GDF SUEZ, IBERDROLA, ENI, RWE, E.ON, GASNATURAL FENOSA.
]]>7669http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7669Thu, 23 May 2013 00:00:00 +0100
« L’approbation de ce plan d’investissement est une étape majeure dans le développement du site d’Anvers pour en faire une des plateformes les plus rentables de la branche Raffinage-Chimie de Total », a déclaré Patrick Pouyanné, directeur général de la branche Raffinage-Chimie de Total. « Avec ce projet, Total illustre sa volonté non seulement de rester parmi les leaders du raffinage et de la pétrochimie en Europe, mais aussi sa capacité à adapter son outil industriel à l’évolution des marchés en réduisant ses capacités de production et en les orientant vers des produits à plus forte valeur ajoutée qui respectent les normes environnementales les plus strictes. »

Deux projets d’investissements majeurs seront réalisés à court terme :
La construction d’un nouveau complexe de raffinage, comprenant une unité de désasphaltage au solvant et un hydrocraqueur visant à convertir les fiouls lourds en diesel et en fioul domestique désulfurés. Il répond à l’évolution de la demande vers des produits à très basse teneur en soufre dont l’impact environnemental est plus faible. La mise en service de ce complexe est prévue pour début 2016.
La construction d’une nouvelle unité convertissant les gaz récupérés lors du processus de raffinage en matières premières pour les unités pétrochimiques, remplaçant ainsi le naphta, matière première dérivée du pétrole plus coûteuse. Ce projet renforce l’intégration entre les unités de raffinage et de pétrochimie de la plateforme et, par conséquent, la compétitivité de ces dernières. La mise en service de cette unité est prévue pour début 2017.

Dans le cadre de ce plan de modernisation, deux unités de production parmi les plus anciennes du site seront arrêtées car elles ne sont plus compétitives dans le contexte économique mondial :
Le vapocraqueur le plus petit et le plus ancien, actuellement hors service par manque de débouchés commerciaux, sera définitivement fermé et démantelé.
La ligne de production de polyéthylène la plus petite et la plus ancienne sera fermée fin 2014, une fois réalisés les investissements sur d’autres lignes de polyéthylène destinés à produire une nouvelle gamme de polymères innovants.
Les effectifs sur la plateforme d’Anvers seront maintenus à environ 1 700 salariés. Il sera proposé à tous les collaborateurs des activités arrêtées de poursuivre leur carrière sur les nouvelles unités de production qui vont faire l’objet d’investissements sur la plateforme.

<strong>A propos de la plateforme d’Anvers de Total </strong>
Dans la zone portuaire d’Anvers, Total compte trois sites de production, formant une plateforme intégrée de raffinage et de pétrochimie. Les activités de la plateforme couvrent la production de divers produits pétroliers (fioul lourd, essence, GPL, diesel, kérosène…) et de produits chimiques de base (oléfines, fractions C4 et hydrocarbures aromatiques) dont certains sont transformés en polymères (polyéthylène haute densité). La plateforme d’Anvers compte environ 1 700 collaborateurs. Ses produits sont employés pour de nombreuses applications domestiques et industrielles, telles que les emballages et le secteur automobile.

<a href="http://www.euro-petrole.com/raffinerie-d-anvers-total-l-43" target="blank" class="lien">Voir le site de la raffinerie d'Anvers</a>]]>7668http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7668Wed, 22 May 2013 00:00:00 +0100
S.E. Dr. Mohammed Bin Saleh Al Sada, Ministre de l’Energie et de l’Industrie du Qatar et Président de QPI, souligne qu’il s’agit d’une étape supplémentaire dans la mise en œuvre de la stratégie de QPI consistant à développer son activité à l’étranger et particulièrement en Afrique. Il salue également l’occasion de renforcer les relations entre le Qatar et le Congo et soutient Total E&amp;P Congo dans son programme de développement.

Christophe de Margerie, Président-directeur général de Total, se réjouit de ce nouvel accord, qui s’inscrit dans le cadre du partenariat stratégique en Afrique signé entre Total et QPI le 25 mars 2010. Il souligne que cet accord renforcera à la fois les liens bien établis avec QPI et l’engagement de Total à poursuivre le développement de l’industrie pétrolière au Congo.

S.E. Jean-Jacques Bouya, Ministre à la Présidence chargé de l’aménagement du territoire et de la délégation générale aux grands travaux de la République du Congo, présent au Doha 13th Forum et mandaté par S.E. Denis Sassou-Nguesso, Président de la République du Congo, exprime sa satisfaction à propos de la collaboration de QPI avec la République du Congo et Total, valorisant ainsi le développement des ressources pétrolières du Congo. Ce partenariat ouvre une étape nouvelle de coopération entre la République du Congo et le Qatar.

<strong>A propos de Qatar Petroleum International (QPI)</strong>
Créée en 2006, QPI est une filiale à 100% de Qatar Petroleum, la société pétrolière nationale de l’Etat du Qatar. QPI a été établie en vue de promouvoir à l’échelle mondiale les intérêts de l’Etat du Qatar dans les secteurs de l’amont, de l’aval, du gaz et de l’énergie.
QPI, en tant que partie prenante de la stratégie de diversification, d’expansion et d’investissement du Qatar et à travers ses partenariats stratégiques avec des sociétés internationales du secteur de l’énergie, met progressivement en place son rôle d’investisseur international majeur dans ce secteur.
QPI s'est bâti une réputation dans l’amont pétrolier, l’aval pétrochimique , le gaz et l'électricité en explorant, et capitalisant sur les opportunités d’investissement et d’acquisition. Le portefeuille de QPI, de plusieurs milliards de dollars, est d’envergure mondiale, comprenant des partenariats en Afrique, en Amérique du Nord (États-Unis et Canada), à Singapour, au Royaume-Uni, en Italie et au Vietnam.

<strong>A propos de Total</strong>
Total est l’un des tout premiers groupes pétroliers et gaziers internationaux, exerçant ses activités dans plus de 130 pays. Le Groupe est également un acteur de premier plan de la chimie. Ses 97 000 collaborateurs développent leur savoir-faire dans tous les secteurs de ces industries : exploration et production de pétrole et de gaz naturel, raffinage et distribution, énergies nouvelles, trading et chimie. Ils contribuent ainsi à satisfaire la demande mondiale en énergie, présente et future.]]>7667http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7667Wed, 22 May 2013 00:00:00 +0100
These competitive contract awards represent an important next step towards Pacific NorthWest LNG designing and constructing a world-class LNG export facility in the District of Port Edward, near Prince Rupert, British Columbia. As part of the FEED process, and to build Canadian LNG engineering expertise, Pacific NorthWest plans to recruit and hire up to 30 Canadian engineers who will be temporarily embedded with the FEED contractors over the next one to two years.

“This world-class engineering and design work provides a tremendous opportunity to begin the process of creating an LNG knowledge center here in Vancouver,” said Greg Kist, President of Pacific NorthWest LNG. “Hiring Canadian engineers and placing them in companies with decades of international experience in LNG engineering will ultimately pay long-term dividends in establishing a base of Canadian LNG engineering expertise in our British Columbia operations.”

The FEED and Engineering, Procurement, Construction and Commissioning (EPCC) bid is expected to be complete by August 2014. At the end of 2014 Pacific NorthWest LNG partners, Malaysia’s national energy company, PETRONAS and Japex, plan to make the final investment decision on the project.

Following completion of the FEED work and awarding of the engineering, procurement, construction and commissioning work, the Canadian team of engineers will be mobilized to the Pacific NorthWest LNG’s Vancouver office or at the site in the Prince Rupert area.

“LNG development is a once-in-a-lifetime opportunity to gain a foothold in a global industry, create wellpaying jobs for British Columbians today, and keep us on the path to a debt-free B.C.,” says British Columbia’s Premier Christy Clark. “Pacific NorthWest LNG’s announcement of its FEED contracts is another positive step forward towards growing this industry and creating lasting benefits for generations to come.”

“This is an exciting step for Pacific NorthWest LNG,” said Kist. “Not only are we moving forward in our plans to build a major LNG export facility here in British Columbia, we are developing a core of Canadian engineering expertise for a promising new segment within the Canadian energy industry. This investment in skills training will help ensure that we establish and grow our LNG capacity and operations for many years.”

<strong>About Pacific NorthWest LNG</strong>
Pacific NorthWest LNG is planning to build a world-class LNG export facility on Canada’s West Coast at Lelu Island in Port Edward, near Prince Rupert, British Columbia. The proposed facility will comprise an initial development of two LNG trains of six million tonnes per annum (mtpa) each, and a subsequent development of a third train of six mtpa. The proposed facility would liquefy and export natural gas produced by Progress Energy Canada in northeastern British Columbia. Pacific NorthWest LNG is committed to generating new economic and social benefits for the local community, British Columbia and Canada in an environmentally safe and sustainable manner. Pacific NorthWest LNG is principally owned by PETROLIAM NASIONAL BERHAD (PETRONAS), Malaysia’s national energy company

<a href="http://www.euro-petrole.com/terminal-lng-pacific-norwest-lng-l-1665" target="blank" class="lien">See the site of Pacific NorthWest LNG Terminal</a>]]>7666http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7666Wed, 22 May 2013 00:00:00 +0100
Le projet comprendra :

- deux trains de GNL de six millions de tonnes par an, les unités de procédés et les installations marines,
les installations de pré-traitement, les utilités et la centrale électrique,
- les installations hors site dont les bâtiments et les installations de jetée.

Ce contrat fait partie d’un appel d’offre pour des conceptions multiples.

Le centre opérationnel de Technip à Rome (Italie) réalisera le contrat avec l’équipe projet du consortium à Séoul (Corée) et Pékin (Chine). Technip sera en charge des trains de GNL, des unités de procédés et des installations marines. Le projet devrait s’achever au second semestre 2014.

Marco Villa, Senior Vice President pour la Région B* de Technip, a commenté : « Ce contrat renforce notre position dans la liquéfaction de gaz naturel, en apportant nos larges connaissances et capacités de conception au projet de notre client. Il est également en ligne avec notre stratégie consistant à nous engager dès les premières phases d’un projet. »

* La Région B de Technip est composée de l’Italie, la Grèce, l’Europe de l’Est/Russie/CEI et l’Amérique du Sud. Elle est également en charge des activités Onshore-Offshore au Canada.

<strong>A propos de Technip</strong>
Technip est un leader mondial du management de projets, de l’ingénierie et de la construction pour l’industrie de l’énergie.

Des développements Subsea les plus profonds aux infrastructures Offshore et Onshore les plus vastes et les plus complexes, nos 36 500 collaborateurs proposent les meilleures solutions et les technologies les plus innovantes pour répondre au défi énergétique mondial.

Implanté dans 48 pays sur tous les continents, Technip dispose d’infrastructures industrielles de pointe et d’une flotte de navires spécialisés dans l’installation de conduites et la construction sous-marine.

<a href="http://www.euro-petrole.com/terminal-lng-pacific-northwest-lng-l-1665" target="blank" class="lien">Voir le site de Pacific NorWest LNG</a>]]>7665http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7665Wed, 22 May 2013 00:00:00 +0100
The purpose of the project is to process shale gas produced from British Columbia’s North Montney region into LNG that is suitable for export. The contract calls for FEED and early detailed engineering work for a two-train LNG plant with a yearly capacity of 12 million tons and associated shipping facilities. Associated facilities include utilities, storage, loading, ship berthing and personnel accommodation facilities. This project allows KBR to build on our extensive Canadian experience and resources including work that is already on-going in other parts of British Columbia.

"We are pleased to play an important role in this world-scale facility. This award is further indication of KBR's position as a leading provider of gas monetization solutions for our clients around the world," said Mitch Dauzat President, KBR Gas Monetization. "We look forward to working with Pacific NorthWest and our partner JGC Corporation on this historic LNG export facility."

<strong>About KBR</strong>
KBR is a global engineering, construction and services company supporting the energy, hydrocarbon, power, industrial, civil infrastructure, minerals, government services and commercial markets.

<a href="http://www.euro-petrole.com/terminal-lng-pacific-norwest-lng-l-1665" target="blank" class="lien">See the site of Pacific NorthWest LNG Terminal</a>]]>7664http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7664Wed, 22 May 2013 00:00:00 +0100
Special attention was paid to the progress with the South Stream project. The meeting participants highlighted the mutual interest in completing the project as soon as possible and confirmed that the gas pipeline construction in Serbia would start in line with the agreements reached in late 2013.

In addition, the parties discussed the Russian gas export to Serbia under a long-term contract.


<strong>About South Stream pipeline</strong>

In 2012 Gazprom Group supplied Serbia with 1.5 billion cubic meters of natural gas.

Srbijagas is a state-owned company dealing with natural gas transmission, distribution and storage in Serbia.

With a view to diversify the natural gas export routes Gazprom is implementing a project for the construction of a gas pipeline running under the Black Sea to the countries of Southern and Central Europe – the South Stream project. Intergovernmental agreements were signed with Bulgaria, Serbia, Hungary, Greece, Slovenia and Croatia in order to implement the onshore gas pipeline section.

In November 2009 South Stream Serbia AG joint project company was registered. Gazprom holds a 51 per cent stake in the company and Srbijagas – a 49 per cent stake.

The Banatski Dvor UGS facility was ceremonially put onstream on November 21, 2011. The UGS facility is one of the largest gas storages in Southeastern Europe. Its working gas capacity makes up 450 million cubic meters, peak deliverability – 5 million cubic meters per day.

In October 2012 a final investment decision was approved for the South Stream project in Serbia.

In February 2013 the Skupstina (Parliament) of the Republic of Serbia adopted the Law on the Public Interest and the Special Expropriation and Permitting Procedures with regard to the South Stream Construction.

In March 2013 a long-term contract was signed for Russian gas supplies to Serbia in the amount of up to 1.5 billion cubic meters of gas annually for a period of 10 years. Gas will be conveyed via the existing route and in the future – via the South Stream gas pipeline.]]>7663http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7663Wed, 22 May 2013 00:00:00 +0100
The lump-sum contract calls for FEED and early detailed engineering work for a two-train LNG plant with a yearly capacity of 12 million tons (6 million tons per train), and associated shipping facilities. The plant will be constructed on Lelu Island, Prince Rupert, British Columbia, and the FEED work is scheduled for completion by the end of 2014.

The purpose of this project is to process shale gas produced from British Columbia's North Montney region into LNG suitable for export. In addition to the two 6-million ton trains, the plant is scheduled to include associated utilities, storage, loading, ship berthing and personnel accommodation facilities. JGC will be undertaking the project as part of a joint venture led by American engineering company KBR.

Client Pacific Northwest LNG has awarded FEED contracts to several other groups besides the JGC/KBR join venture. When FEED work is complete at the end of 2014, the client will select the contractor of its preferred FEED package for receipt of the EPC (engineering, procurement, and construction) portion of the project. The start of LNG production is schedule for the end of 2018.

Currently, there are multiple LNG projects utilizing shale gas planned for the North American continent. This project will be JGC's first LNG project undertaken in North America, and we hope very much that we will be able to continue to help contribute to the client's success by being selected for the EPC portion of the project, as well.

JGC has performed EPC work on a variety of projects for Petronas since the 1980's, and is currently performing EPC for an onshore LNG plant expansion project, as well as FEED work for a floating LNG project. With this new contract, we hope to further deepen the relationship of trust between Petronas and JGC.

To date, JGC has constructed LNG plants accounting for 30% of the world's total production capacity, and is currently involved in six new LNG plant construction projects in Australia, Indonesia, Malaysia, Papua New Guinea, and Russia, respectively. In addition, JGC is also performing FEED work for an onshore LNG plant in Mozambique, as well as offshore LNG plants in Indonesia and Malaysia. As a world-class LNG contractor, we plan to continue to promote and expand our activities in the future.

<a href="http://www.euro-petrole.com/terminal-lng-pacific-northwest-lng-l-1665" target="blank" class="lien">See the site of Pacific NorthWest LNG Terminal</a>]]>7662http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7662Wed, 22 May 2013 00:00:00 +0100
CEOs of eight European energy companies (Fulvio CONTI, Gertjan LANKHORST, Gérard MESTRALLET, Ignacio GALAN, Paolo SCARONI, Peter TERIUM, Johannes TEYSSEN, Rafael VILLASECA MARCO (1)) have drawn to the attention of EU leaders the urgent need to tackle the perilous situation facing the European energy sector.

Meeting in Brussels, the day before the European Council focused on energy and tax fraud on 22 May 2013, these eight energy companies agreed on a joint statement to underline the seriousness of the current challenges facing the sector and to propose appropriate policy actions. Indeed the current lack of visibility on energy policies and regulatory uncertainty will inevitably lead to an absence of energy investments with negative effects on security of supply, employment and reactivation of the European economy. The status quo is simply not an option.

The signatories remain committed to the EU’s ambition for an energy policy based on the principles of competitiveness, security of supply and sustainable development, and they also fully adhere to the need for liberalization of energy markets. We see each of these elements as preconditions for competitive energy for industrial customers and citizens. However, the reality that each of the respective energy companies has experienced, over recent years, is that EU and some national energy policies have not delivered the full expected benefits. In concrete terms, European energy companies are the subject of a perfect storm which is endangering security of supply and the transformation towards a low-carbon economy, as well as undermining their capacity to attract capital.

It is, however, not too late for a revitalized EU approach to ensure competitive energy prices and a secure supply of energy for European citizens. Concurrently, this action would serve to restore the confidence of energy companies in the attractiveness of a European energy market. It is absolutely crucial that this revamped EU approach continues to support the fight against climate change, in addition to encompassing the following fresh elements:

An improved market design, including a European coordinated approach to capacity mechanisms in which all assets contributing to the security of supply of European customers are fairly remunerated.
A European carbon market able to support climate-friendly technologies and in which a reliable perspective is provided, notably, by establishing ambitious but realistic and stable post-2020 greenhouse gas emissions targets.
A more sustainable approach to the promotion of renewables so as to reduce costs for citizens and favour greater convergence between Member States.
A strengthening of the policy framework to triggerinvestments in promising technologies, such as energy storage, new renewables, carbon capture and storage, smart grids and meters and shale gas.


The CEOs of the eight energy companies very much look forward to EU political leaders taking stock of the critical situation the energy sector is facing. They must also define a new policy direction based on the elements included in the joint statement which are centred on the contribution that investments in the energy sector make, not only in providing a secure and efficient product, but also through creating jobs and reactivating the economy in an efficient way.

(1)Representing the following energy companies: ENEL, GASTERRA, GDF SUEZ, IBERDROLA, ENI, RWE, E.ON, GASNATURAL FENOSA.]]>7661http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7661Wed, 22 May 2013 00:00:00 +0100
Quote:
Pursuant to what was stated in section 7.7.10 of the Partnership's Periodic Report to December 31, 2012 that was published on March 15, 2013 (ref. no. 2013-01-00632 and 2013-01-006328), the Partnerships’ Immediate Reports dated May 15, 2013 (ref. no. 2013-01-062236 and 2013-01-062239) concerning the discovery of significant signs of petroleum (natural gas) at the Karish 1 exploratory well that is in the area of License 366 / Alon C ("Karish 1 Well" or "the Well"), and in accordance with information provided to the Partnerships by the well operator, Noble Energy Mediterranean Ltd ("the Operator"), the Partnerships announces the discovery of natural gas at the Karish 1 Well .

The Karish 1 Well is a maritime borehole located about 75 km north-west of the Haifa coast, at a water depth of 1,740 meters. As reported in the Immediate Report dated 15 May, 2013, the Well reached a final depth of 4,790 meters from sea level (including the depth of the water), and significant signs of petroleum (natural gas) were discovered in the target strata .

The Operator carried out tests at the Well, including Logging While Drilling and Wireline Logging, which included electrical, seismic and magnetic tests as well as tests of the composition of the natural gas, the rocks and liquids in the Karish reservoir. The results and their analysis, as informed to the Partnerships by the Operator, satisfied the Partnerships as to the existence of natural gas at the Well .

According to the initial assessments by the Operator and the Partnerships, the quantity of natural gas discovered at the Well justifies testing and estimating the quantity of resources of natural gas in the reservoir and carrying out an assessment and estimation of the amounts of natural gas that are economically viable to be extracted .

<strong>In the light of the foregoing, the Karish 1 Well is a natural gas discovery .</strong>

The Partnerships hereby clarifies:
A discovery is defined in SPE-PRMS as "a single reservoir or a number of reservoirs of petroleum, which based upon production tests, sampling or logging show that at that reservoir there is a significant quantity of hydrocarbons that can be moved; in this respect, "significant" indicates there is evidence of a sufficiently significant amount of petroleum to justify estimation activities of the amount of resources included in the well and actions to estimate the quantities that are economically viable to extract." In this meaning of "discovery" as used in this Report, "discovery" is not that of the Petroleum Law, 1952; only the Oil Commissioner is authorized to approve a discovery in the meaning of the law .

Warning of forecast information
the above assessments concerning the existence of natural gas at the Well, and other aspects concerning the Well, are based upon information, assessments and estimates that have been received from the Operator, including based on the tests carried out as stated above, and these are forecast information. At this point these are assessments and estimates only for which there can be no certainty. The above assessments and estimates are likely to be updated as additional information is obtained, including the results of the continuing analysis of the drilling, and/or carrying out assessment boreholes (if such shall be conducted), and/or as a result of all the factors related to the exploration and production projects for natural gas .

<strong>The Partners in the "Karish 1" Well and their holdings :</strong>
Noble Energy Mediterranean Ltd. 47.059%
Delek Drilling Limited Partnership 26.4705%
Avner Oil Exploration - Limited Partnership 26.4705%

<strong>About The Delek Group</strong>
The Delek Group, Israel’s dominant integrated energy company, is the pioneering leader of the natural gas exploration and production activities that are transforming the Eastern Mediterranean’s Levant Basin into one of the energy industry’s most promising emerging regions. Having discovered Tamar and Leviathan, two of the world’s largest natural gas finds since 2000, Delek and its partners are now developing a balanced, world-class portfolio of exploration, development and production assets with total gross natural gas resources discovered since 2009 of approximately 33 TCF .

In addition, Delek has built an extensive network of global downstream assets, including 1,900 gas stations and convenience stores in the U.S., Europe and Israel, and petroleum refineries in the U.S. Delek also holds significant interests in leading water desalination, power generation, insurance and automotive companies .

In 2012, the Company's revenues were NIS 72 billion ($ 19 billion). Delek Group's shares are traded on the Tel Aviv Stock Exchange (TASE: DLEKG) as part of the TA25 Index.]]>7660http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7660Wed, 22 May 2013 00:00:00 +0100
"Il nous faut des standards plus poussés en matière de gestion du risque. Nous pensons que les règles que nous sommes en train d'ériger pourraient servir de référence au niveau international" a déclaré Ivo Belet (PPE, BE), dont le rapport a été adopté ce mardi par 572 voix contre 103 et 13 abstentions. Se référant à l'Arctique, M. Belet a estimé que "l'UE n'ayant pas d'eaux territoriales dans la région du pôle nord, il est difficile pour nous d'y envisager un moratoire sur l'exploration pétrolière et gazière".

<strong>Capacité financière de couvrir les dommages causés</strong>

Tous les opérateurs devraient montrer qu'ils disposent de "suffisamment de ressources matérielles, humaines et financières pour limiter et corriger l'impact d'un accident majeur éventuel". L'autorisation ne peut être donnée faute de preuve sur la "capacité financière du demandeur (...) à assumer les responsabilités qui pourraient découler des opérations".

<strong>Rapport de danger majeur</strong>

Les compagnies de forage devront soumettre aux autorités nationales, avant le début des opérations, un rapport spécial détaillant l'installation de forage, les dangers majeurs potentiels et les mesures prévues pour protéger les travailleurs.

<strong>Plans d'urgence</strong>

Les compagnies devront fournir un plan interne d'intervention d'urgence pour chaque installation, avec une description complète de l'équipement et des ressources disponibles, les mesures à prendre en cas d'accident ainsi que celles prises pour limiter les risques et alerter rapidement les autorités.

De leur côté, les Etats membres devront préparer des plans d'intervention d'urgence externes, couvrant tous les sites de forage en mer sous leur juridiction. Ces plans devront spécifier les rôles et obligations financières respectives des compagnies de forage, des autorités compétentes et des équipes d'intervention d'urgence.

<strong>Arctique</strong>

Les députés soulignent que les eaux de l'Arctique jouent un rôle important dans l'atténuation du changement climatique et rappellent le besoin de protéger la région. Ils encouragent les Etats membres siégeant au Conseil de l'Arctique à "promouvoir activement les normes les plus strictes en ce qui concerne la sécurité environnementale dans cet écosystème vulnérable et unique, en mettant par exemple au point des instruments internationaux en matière de prévention, de préparation et de réaction à la pollution pétrolière marine dans l'Arctique".

<strong>Application et transposition</strong>

Les Etats membres dépourvus de littoral ou d'installations offshore sous leur juridiction mais ayant des compagnies enregistrées sur leur territoire ne devront appliquer que certaines mesures prévues dans la directive. Les Etats membres ont deux ans pour transposer le texte en droit national. Pour les installations existantes, le délai de transposition est de cinq ans.]]>7653http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7653Wed, 22 May 2013 00:00:00 +0100
“Our 2013 Gulf of Mexico exploration program is off to an outstanding start, as Phobos marks our third significant deepwater success this year,” Anadarko Sr. Vice President International and Deepwater Exploration Bob Daniels said. “Phobos is our first well in the previously untested Sigsbee Escarpment area of the Gulf of Mexico and successfully tested a significant four-way structure in the Lower Tertiary. Phobos’ close proximity to our Lucius project is expected to further enhance the economics of this potential future development.”

The Phobos discovery, located in Sigsbee Escarpment block 39, was drilled to a total depth of 28,675 feet in approximately 8,500 feet of water, approximately 11 miles south of Anadarko’s Lucius discovery, which is under development. Anadarko currently is incorporating the data from the Phobos well to determine future activities.
Anadarko is the operator of the Phobos discovery with a 30-percent working interest.

Other co-owners in Phobos are Plains Exploration &amp; Production Company (NYSE: PXP) with a 50-percent working interest and Exxon Mobil Corporation (NYSE: XOM) with a 20-percent working interest.

<strong>About Anadarko</strong>
Anadarko Petroleum Corporation’s mission is to deliver a competitive and sustainable rate of return to shareholders by exploring for, acquiring and developing oil and natural gas resources vital to the world’s health and welfare. As of year-end 2012, the company had approximately 2.56 billion barrels-equivalent of proved reserves, making it one of the world’s largest independent exploration and production companies.]]>7659http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7659Tue, 21 May 2013 00:00:00 +0100 The document was signed by head of SOCAR Investments Division and Petkim’s Chairman of Board Vagif Aliyev, Chief Executive Officer at SOCAR Turkey Kenan Yavuz, the Secretary General of the Spanish company Tecnicas Reunidas Jose Pedro Sebastian De Erice, Executive Director of Business Development Enrique Alsina Massan and by the representatives of Saipem, GS Engineering and Itochu. Vagif Aliyev stressed that

the groundbreaking ceremony of the STAR Refinery, held on 25 October 2011 with the participation of the President of the Republic of Azerbaijan Ilham Aliyev and Turkish Prime Minister Recep Tayyip Erdo&amp;#287;an, came to a very important stage. According to him, STAP Refinery, refinery, petrochemical, energy, logistics projects with Petkim, as well as TANAP pipeline will contribute to the strategic partnership between Azerbaijan and Turkey. CEO of the Spanish Tecnicas Reunidas Juan Llado said that despite the global economic crisis, huge investments in STAR Refinery are continued. He expressed confidence in successful completion of construction works. SOCAR Turkey CEO Kenan Yavuz said that operations of the Refinery, the most important step in refinery-petrochemistry-energy-logistics integration, were anticipated to start within 51 months after the said signatures affixed. With 10 million tons/year capacity, STAR refinery will handle oil types such as Ural, Azeri Light and Kirkuk. The project will be conducted in full compliance with the highest European standards.

<a href="http://www.euro-petrole.com/raffinerie-star-refinery-l-1668" target="blank" class="lien">See the site of STAR refinery</a>]]>7657http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7657Tue, 21 May 2013 00:00:00 +0100
The total value of new contracts acquired from January 2013 to date in the E&amp;C Business Unit (some of which will be communicated in the next weeks) is approximately €6.1 billion, and supports the likelihood of achieving a full-year order intake, similar to recent years, of approximately €11 billion.

CEO U. Vergine emphasizes: “Although this is a partial intermediate result for 2013, we are very pleased; not only does it help guarantee our target activity levels in Saipem, but we are progressing with our objective of improving the marginality of our order backlog. The E&amp;C contracts acquired since January imply margins that so far represent an improvement of at least 40% compared with those acquired in 2012”.

<strong>About Saipem</strong>
Saipem is organised into two Business Units: Engineering &amp; Construction and Drilling, with a strong bias towards oil &amp; gas related activities in remote areas and deepwater. Saipem is a leader in the provision of engineering, procurement, project management and construction services with distinctive capabilities in the design and execution of large-scale offshore and onshore projects, and technological competences such as gas monetisation and heavy oil exploitation.]]>7656http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7656Tue, 21 May 2013 00:00:00 +0100
The EIB will finance a development program that includes improvements in natural gas transport, energy efficiency, optimisation of refining processes, development and production of petrochemical derivatives and carbon dioxide storage. This will also include programs for systems development in renewable energy, biofuels and transport solutions.

The investments that will be carried out between 2013 and 2016 support the European Union and the EIB objectives to develop sustainable, competitive and secure energy solutions, promoting energy efficiency and the technical capacity of European companies. This supports the company’s R&amp;D projects, a priority for Repsol, which has a technological development strategic plan as part of its business strategy.

Most projects are developed at the Repsol Technology Centre, in Móstoles (Madrid), one of the most advanced in Europe and the largest in Spain, spanning 56,000 m2, with more than 400 scientists and researchers working at the facilities that were opened in 2002. The centre is involved in numerous national and international research projects, working together with universities and companies specialising in multiple areas.

Thanks to its commitment to technology, Repsol has developed innovative projects for the industry that have been recognized internationally, including the Kaleidoscope seismic imaging project, which creates faster and sharper subsea visualisation while also being less invasive with the environment, or the Sherlock project, which allows for greater extraction of information from rocks containing hydrocarbons or for CO2 storage.]]>7655http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7655Tue, 21 May 2013 00:00:00 +0100
The governments further expressed their commitment to engage in developing the necessary gas interconnections to ensure that Nabucco can also supply the countries in the Southern and Central-North dimension of Europe.

The State Parties call on the European Council, which will meet on 22 May to address the completion of the Internal Energy Market, to note the wider potential of Nabucco to provide access to new sources of gas for promoting growth and competition at the European level. The State Parties also approached the European Commission to continue to provide the project with the necessary regulatory and technical assistance.

The participants at the Committee Meeting also welcomed the progress of the project since the previous committee meeting was held in Budapest in April, and the work done by the authorities in the transit countries to ensure the successful implementation of the project. In particular they highlighted the efforts of the Nabucco Tax Subcommittee to align taxation issues under the Nabucco Intergovernmental Agreement and its detailed recommendation regarding the application of the tax provisions under the Agreement. States Parties now have an expert basis from within the Nabucco Committee to complete the necessary tax instruments or agreements under their domestic legal order.

Frank Siebert, CFO of NABUCCO Gas Pipeline International GmbH said: “Investors need predictability and stability when it comes to cash flow for a project. We have now achieved this basis thanks to the recommendations of the Nabucco Tax Subcommittee.”

The declaration highlights the complementarity of the Nabucco and TANAP (Trans Anatolian Pipeline) projects, and welcomed the progress made in the realization of TANAP by the Turkish and Azeri authorities. Delegations from both countries were also present at the meeting. Nabucco recently concluded a Memorandum of Understanding with TANAP to ensure effective cooperation in the realization of both projects.

Reinhard Mitschek, CEO, NABUCCO Gas Pipeline International GmbH said: “We have reached several milestones since the Budapest Nabucco committee meeting: Bulgaria became the second country to grant Nabucco the environmental permit to construct, we launched the registration phase of the Open Season to levels of interest that surpassed expectations. The national regulators also granted Nabucco a prolongation of the exemption from EU legislation on Third Party Access, in alignment with the delivery timelines of Shah Deniz gas. Nabucco is the shortest route to the markets of South Eastern Europe, and remains the best option to open the Southern Gas Corridor.”]]>7654http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7654Tue, 21 May 2013 00:00:00 +0100
Haradh GOSP-1 is a critical plant for Saudi Aramco, and its three motor-driven compressors play a vital role by maintaining the compression of the gas after it is separated from the oil. The previous compressor control system used programmable logical controllers, which GE replaced with Mark VIe technology, along with GE’s OptiComp compressor control algorithms and remote control capability from the plant’s existing distributed control system.

“As the world leader in the production of petroleum-based energy, we at Saudi Aramco hold ourselves to the highest standards of excellence and have very specific requirements when it comes to compressor control and protection,” said Ahmad Saleh Haradh, GOSP-1 Saudi Aramco project engineer. “From the start, GE worked closely with us to understand our unique needs and specifications and remained flexible throughout the entire project. The updated control system is now in full operation and is satisfying all of our performance expectations.”

“Saudi Aramco is a key partner of GE, and we demonstrated to them our ability to meet their specific program requirements through extensive demonstrations and testing of our solution from the very beginning. Robust planning and our close partnership with the Saudi Aramco team led to the smooth installation of a highly customized control package within a short timeframe. This project adds to our proven experiences and successes in the region where we have over 80 years of presence and a strong understanding of local industry needs,” said Rami Qasem, president and CEO, GE Oil &amp; Gas, Middle East, North Africa and Turkey.

The solution features GE’s Mark Vle control platform with OptiComp control software and provides capabilities such as anti-surge, motor limit, pressure control, discharge pressure and pressure override control. GE also saved significant plant space by building a single platform to control all three compressors (two high-pressure compressors running in parallel and one low-pressure compressor running in series). Additionally, GE performed surge tests on all units to help ensure optimal compressor performance. These tests enabled GE to enhance the performance of the low-pressure compressor and reduce degradation, ultimately expanded the operating envelope for that compressor.

Saudi Aramco, the national oil and gas company, is a fully integrated, global petroleum enterprise and a world leader in the exploration, production, refining, distribution, shipping and marketing of oil and gas. The company manages proven conventional reserves of 260 billion barrels of oil and manages the fourth largest gas reserves in the world, 263 trillion cubic feet.

<strong>About GE</strong>
GE (NYSE: GE) works on things that matter. The best people and the best technologies taking on the toughest challenges. Finding solutions in energy, health and home, transportation and finance. Building, powering, moving and curing the world. Not just imagining. Doing. GE works. For more information, visit the company's website at www.ge.com.

<strong>About Measurement &amp; Control</strong>
Measurement &amp; Control is a leading innovator in advanced, sensor-based measurement; non-destructive testing and inspection; flow and process control; turbine, generator, and plant controls; and condition monitoring. Providing healthcare for our customers’ most critical assets, we deliver accuracy, productivity and safety to a wide range of industries, including oil &amp; gas, power generation, aerospace, metals and transportation. Headquartered in Boston, USA, Measurement &amp; Control has more than 40 facilities in 25 countries and is part of GE Oil &amp; Gas.]]>7652http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7652Tue, 21 May 2013 00:00:00 +0100
"We need more important standards when it comes to risk management. We believe that the rules we are currently coming up with can be used as a template at international level," said Ivo Belet (EPP, BE), who steered the legislation through Parliament that was adopted today by 572 votes to 103, with 13 abstentions. Referring to the Arctic, Mr. Belet noted that "the EU has no territorial waters in the North Pole area so it's difficult for us to envisage a moratorium on gas and oil exploration in this area."

<strong>Financial ability to remedy all damage caused</strong>

All operators will need to ensure they have access to "sufficient physical, human and financial resources to minimise and rectify the impact of a major accident". No licence will be granted unless the applicant has provided evidence that "adequate provision has been or will be made to cover liabilities potentially deriving from its offshore oil and gas operations".

<strong>Major hazards report</strong>

Drilling companies will be required to submit to the national authorities, before starting operations, a special report, describing the drilling installation, potential major hazards and special arrangements to protect workers.

<strong>Emergency response plans</strong>

Companies will also have to provide an internal emergency plan, giving a full description of the equipment and resources available, action to be taken in the event of an accident and all arrangements made to limit risks and give the authorities early warning.

At the same time, EU member states will have to prepare external emergency response plans covering all offshore drilling installations within their jurisdiction. These plans will specify the role and financial obligations of drilling companies as well as the roles of relevant authorities and emergency response teams.

<strong>Arctic</strong>

MEPs acknowledge the Arctic waters' important role in mitigating climate change and the need to ensure environmental protection of the Arctic and they encourage member states who are members of the Arctic Council "to actively promote the highest standards with regard to environmental safety in this vulnerable and unique ecosystem, such as through the creation of international instruments on prevention, preparedness and response to Arctic marine oil pollution".

<strong>Application and transposition</strong>

Member states with offshore waters that have no offshore oil and gas operations under their jurisdiction, and landlocked countries with companies registered in their territories will need to apply only a limited number of this directive's provisions. Member states will have two years to transpose the directive into their national laws, whilst for existing installations the deadline for transposition will be five years.]]>7651http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7651Tue, 21 May 2013 00:00:00 +0100
In the aftermath of the "Deepwater Horizon" accident in the US Gulf of Mexico in May 2010 the Commission reviewed the existing Member States' safety frameworks for offshore operations and proposed new legislation to ensure that the world's highest safety, health and environmental standards apply everywhere in the EU marine waters.

Today the European Parliament adopted the EU legislative proposal on the safety of offshore oil and gas operations in the EU. The Council still need to formally approve the Directive. The main elements of the agreed directive are the following:

- Licensing. The Directive introduces clear rules for effective prevention and response of a major accident. The licensing authority in the Member States will have to make sure that only operators which can demonstrate technical and financial capacities necessary to ensure the safety of offshore activities and environmental protection are allowed to explore for, and produce oil and gas in EU waters. Public participation will be mandatory prior to the start of exploratory drilling campaigns in previously undrilled areas.

- Independent national competent authorities responsible for the safety of installations will verify the provisions for safety, environmental protection and emergency preparedness of rigs and platforms and the operations conducted on them. If companies do not respect the minimum standards, Member States will take enforcement actions and/or impose penalties; ultimately, operators will have to stop the drilling or production operations.

- Obligatory ex ante risk assessments. Companies will have to prepare a report on major hazards for their installation, containing an extensive risk assessment and risk control measures and an emergency response plan before exploration or production begins. These plans will need to be submitted to national competent authorities who will give a go-ahead.

- Independent verifiers. Operators will need to seek an independent opinion for the safety critical systems and well plans prior to and periodically after an installation is taken into operation.

- Transparency. Information will be made available to citizens allowing to compare the performance of the industry and the activities of the national competent authorities. The confidentiality of whistle-blowers will be protected. Operators registered in Member States will be requested to submit reports of major accidents in which they have been involved overseas to enable key safety lessons to be studied.

- Emergency Response. Companies will prepare emergency response plans based on their rig or platform risk assessments and keep resources at hand to be able to put them into operation when necessary. Member States will likewise take full account of these plans when they compile national emergency plans. The plans will be periodically tested by the industry and national authorities.

- Liabilities. Oil and gas companies will be fully liable for environmental damages caused to the protected marine species and natural habitats. For damage to waters, the geographical zone will be extended to cover all EU marine waters including the exclusive economic zone (about 370 km from the coast) and the continental shelf where the coastal Member State exercises jurisdiction. For water damage, the present EU legal framework for environmental liability is restricted to territorial waters (about 22 km offshore).

- EU Offshore Authorities Group. Offshore inspectors of Member States will work together to ensure effective sharing of best practices and contribute to developing and improving safety standards.

- International. The Commission will work with its international partners to promote the implementation of the highest safety standards across the world. Operators working in the EU will be expected to demonstrate they apply the same policies for preventing major accidents overseas as they apply in their EU operations.]]>7650http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7650Tue, 21 May 2013 00:00:00 +0100
The order consists of ten subsea production control umbilicals totaling approximately 84 kilometers (52.2 miles) in length and two electrical power cables totaling approximately 55 kilometers (34.2 miles) in length. Product manufacturing is planned to be performed at Oceaneering’s facility in Rosyth, Scotland and is expected to commence in the second quarter of 2013 and be completed in the third quarter 2014.

<strong>About Oceaneering</strong>
Oceaneering is a global oilfield provider of engineered services and products, primarily to the offshore oil and gas industry, with a focus on deepwater applications. Through the use of its advanced applied technology expertise, Oceaneering also serves the defense, entertainment, and aerospace industries.]]>7649http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7649Tue, 21 May 2013 00:00:00 +0100
<strong>Deux projets pilotes de bâtiment basse consommation</strong>
Ainsi, à travers une convention de partenariat, le CFBP apporte son soutien aux travaux engagés depuis plusieurs mois par la commune de Saint-Pellerin (Manche) pour la rénovation et l’extension d’une salle communale et lui permettre de répondre aux exigences du label « bâtiment basse consommation » (BBC).

Le CFBP soutient également la commune de Préveranges (Cher) dans la transformation d’un ancien hôtel-restaurant en un bâtiment accueillant la Mairie et la Poste, ainsi que quatre logements sociaux.

<strong>Le rôle du propane en matière d’efficacité énergétique</strong>
L’utilisation du propane - énergie facilement accessible dans les communes rurales - pour la production de chauffage et d’eau chaude contribuera à diviser par 4 le budget énergie de ces deux bâtiments, à diminuer leur consommation d’énergie (par 3 ou 4 selon le projet) et à réduire fortement les émissions de gaz à effet de serre (division par 7 ou par 8).

L’énergie GPL offre des solutions matures qui permettent d’améliorer les performances énergétiques des constructions publiques et résidentielles et d’atteindre en rénovation notamment les exigences imposées par la nouvelle réglementation thermique aux bâtiments neufs. Les gaz propane et butane, également appelés GPL*, ont des qualités multiples et sont adaptés à tous les besoins énergétiques de l’habitat ou du secteur tertiaire.

Ils sont utilisés indépendamment ou simultanément par plus de 11 millions de foyers français pour la cuisson, le chauffage et la production d’eau chaude sanitaire. Facilement transportable et stockable, l’énergie GPL permet de répondre aux besoins en énergie, quels qu'ils soient, en tous points du territoire à des conditions économiques compétitives. L’énergie GPL offre une énergie abondante et pratique grâce à sa mobilité, là où les autres énergies le sont moins ou parfois absentes.

<strong>A propos du Comité Français du Butane et du Propane</strong>
Association de loi 1901, le Comité Français du Butane et du Propane (CFBP) est l’organisation professionnelle de la filière des GPL. Le CFBP représente la filière auprès des différents acteurs politiques et économiques français. En partenariat avec les instances nationales, européennes et internationales, le CFBP contribue à l’élaboration des règles et des normes qui régissent l’exploitation et l’utilisation des GPL. Le CFBP informe le public et les différents services et industries liés aux GPL sur les utilisations et avantages des gaz butane, propane et du GPL carburant sur la sécurité et sur les activités de la profession. ]]>7647http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7647Mon, 20 May 2013 00:00:00 +0100
The purchase price of BP's assets is $1,075 million, plus the market value of inventory, currently estimated at $1,300 million. This amount includes a $100 million purchase price reduction for the clearance with regulatory authorities.

"We are pleased the FTC has concluded its review and we can close this transformational acquisition as planned," said Greg Goff, President and CEO. "This transaction is a unique opportunity for Tesoro to combine the best aspects of two West Coast refining, marketing and logistics businesses resulting in a more efficient world-scale integrated refining, marketing and logistics system."

Tesoro currently owns and operates 263 thousand barrels per day ("mbpd") of refining capacity in the state of California. Upon closing the transaction, Tesoro will begin the process of combining and reconfiguring the two West Coast systems to drive significant operational synergies through the integrated supply of crude oil, enhanced optimization of intermediate feedstocks and product distribution costs, improvements in light product yield and reductions in manufacturing costs and stationary source air emissions. This will include creating one Los Angeles refining complex by combining its existing Los Angeles refinery with the newly acquired and adjoining Carson refinery. This West Coast system work is expected to result in annual synergies of approximately $250 million with an additional capital investment of approximately $225 million.

In addition to the previously announced synergies, the Company plans to drive additional value from the crude oil sourcing flexibility expected through the recently announced unit train unloading and marine loading facility at the Port of Vancouver, WA. The Carson refinery, originally built to run Alaska North Slope crude oil, is an ideal home for cost-advantaged mid-continent crude oil. The Port of Vancouver logistics project, combined with the exceptional marine terminal facilities at Carson, is expected to drive an additional competitive advantage for the combined Tesoro Los Angeles refining complex.

The transaction includes about 800 dealer operated retail stations in Southern California, Nevada and Arizona, the well-established ARCO® brand and associated registered trademarks, and a master franchisee license for the ampm® convenience store brand. The addition of these high volume retail stations to Tesoro's existing retail network will result in a total Southern California station count of about 1,350 retail stations, ensuring ratable off-take for the combined refinery complex gasoline production. This transaction is expected to drive the Company's refining and marketing integration, a key strategic focus for Tesoro, to about 83%, a five percentage point improvement relative to today.

The transaction also includes two complementary assets which are located near the Carson refinery. The first is a 51% ownership in the 400 megawatt gas supplied Watson cogeneration (cogen) facility. This company-operated cogen, the largest in California, provides reliable electricity to the Carson refinery and sells excess electricity to the local utility grid. Post integration, the Company expects the Watson cogen to provide reliable electricity to Tesoro's Wilmington refinery, driving additional operational availability. The second is a 350,000 metric ton per year anode coke calcining operation. This asset upgrades coke from the Carson refinery into valuable calcined anode-grade coke for the aluminum industry. These assets are expected to provide additional cash flow and drive earnings diversification for Tesoro.

Tesoro and Tesoro Logistics LP ("TLLP") have reached an agreement for TLLP to acquire a portion of the Carson logistics assets from Tesoro for an expected transaction value of approximately $640 million. Closing of the logistics transaction is expected to occur concurrent with the BP transaction close. These assets, with expected annual logistics EBITDA of between $60 to $65 million, include six marketing and storage terminal facilities with a total combined throughput capacity of about 225 mbpd and approximately 6.4 million barrels of total storage capacity including 4.5 million barrels which is dedicated commercial storage capacity. The transaction price is expected to include cash of $544 million and Tesoro Logistics equity valued at $96 million. The Company expects to enter into terminalling and throughput agreements with minimum volume commitments, consistent with prior transactions. The remaining Carson logistics assets, consisting of dedicated storage capacity, pipelines and marine terminals, are expected to be offered to TLLP within twelve months post-closing, and have an expected market value of between $450 and $550 million.

The Company expects to fund the estimated $2,375 million transaction with between $500 and $750 million of cash, $500 million in term loan borrowings and nearly $550 million of cash proceeds from the acquisition of logistics assets by TLLP. The remainder of required funds is expected to be sourced with borrowings under Tesoro Corporation's revolving credit facility, which was recently expanded to $3.0 billion.

"This is an exciting opportunity for Tesoro to drive significant shareholder value and is well aligned with our strategic priorities," said Goff. "For essentially the value of inventory, we are adding about a half a billion dollars of base annual EBITDA; expanding refining capacity by nearly fifty percent, excluding Hawaii; driving an over sixty percent increase in the enterprise value of Tesoro Logistics; and adding a pair of high-value complementary integrated assets."

<a href="http://www.euro-petrole.com/raffinerie-de-carson-l-461" target="blank" class="lien">See the site of Carson refinery</a>]]>7646http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7646Mon, 20 May 2013 00:00:00 +0100
The value of the contract for TR will be above 1,100 million US dollars and will have an execution period of 49 months until the commissioning of all the units.

The high standard conversion STAR Refinery will be the most comprehensive oil downstream project of Turkey, with an annual crude oil processing capacity of 10 million tons. By adapting the most advanced technologies and applying the most stringent EU regulations and environmental standards, STAR Refinery will ensure Turkey’s refining sector to substantially reduce its current external deficit of downstream petroleum products by producing naphtha, diesel, jet fuel and LPG.

The contract has been awarded on a lump sum turnkey basis. The design for STAR Refinery will enable to process different types of crude oil such as Urals, Azeri Light and Kirkuk with an overall capacity of 10 million tons/year. The new refinery will be constructed on Petkim peninsula on approximately 2.300 hectares of area.

The refinery will have a yearly production of 0.48 million tons of ultra-low sulphur diesel, 0.16 million tons of naphtha, 0.42 million tons of mixed xylene, 0.16 million tons of jet fuel, 0.32 million tons of LPG, 0.49 million tons of reformate, 0.69 million tons of petro-coke and 0.16 million tons of sulphur at its full capacity operation. With its 63 tanks, the total storage capacity of the refinery will be of 1.640 million tons approximately.

Turkey is a priority market for TR. It has already executed 8 previous projects in Turkey, for companies like TÜPRAS, IPRAS and BOTAS, and two more projects in the field of Nitric Acid and fertilizers for TUGSAS and TOROS GUBRE. This new contract will guarantee a further successful presence in that country in cooperation with Turkish partners and with regard to the substantial new investments to be developed in Turkey.

<strong>About SOCAR</strong>
SOCAR - State Oil Company of Azerbaijan Republic – The State Oil Company of Azerbaijan Republic (SOCAR) is the state-owned oil and natural gas corporation of Azerbaijan. It is considered to be one of the largest oil companies in the world. It produces oil and natural gas, operates the country's two oil refineries and the oil and gas pipelines throughout the country.

<strong>About SOCAR Turkey Enerji A.&amp;#350;</strong>
SOCAR Turkey Enerji A.&amp;#350;. is the most important representative of gradually strengthened economic cooperation between Azerbaijan and Turkey. SOCAR Turkey Enerji A.&amp;#350;.’s goal is to become one of the three major holding companies of Turkey with a turnover of 17 thousand million US dollars in the next five years and also to become the largest manufacturing power until 2023.

<strong>About Técnicas Reunidas</strong>
Técnicas Reunidas is one of the leading international engineering and construction companies for oil and gas production, refining and petrochemicals and power generation projects for a broad spectrum of customers throughout the world. Since 1959, TR has designed and built more than 1000 industrial plants worldwide in more than 50 countries.

<a href="http://www.euro-petrole.com/raffinerie-star-refinery-l-1668" target="blank" class="lien">See the site of STAR Refinery</a>]]>7645http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7645Mon, 20 May 2013 00:00:00 +0100 The decision means that TAP can offer capacity for export of gas volumes from Azerbaijan to Europe for a period of 25 years. In addition, the Commission has approved exemptions from regulated tariffs on both TAP’s initial and expansion capacity, as well as exemption from ownership unbundling for 25 years.

European Union internal market regulation typically requires third party access to all energy infrastructure, including gas pipelines. However, national regulators can grant exemptions to this rule for a limited period of time, in order to facilitate major infrastructure projects such as international pipelines. Provided that all conditions have been met, the European Union then corroborates the decision, offering an exemption from certain provisions in the regulatory framework.

Commenting Kjetil Tungland, TAP’s Managing Director, said: “We are grateful to the European Commission for the swift handling of this exemption. Its signature means that we now have all of the agreements we require ahead of the Shah Deniz Consortium’s decision next month.

"We are absolutely confident that the Trans Adriatic Pipeline is the best solution to transport Caspian gas to Europe, improving the entire region’s energy security. It is the shortest and most technically advanced pipeline, which does not require subsidies or grants and crucially is the most commercially feasible project.”
Lutz Landwehr, TAP’s Commercial Director, added: “The Trans Adriatic Pipeline was the first project to conclude its Funding, Equity and Shareholder agreements with the Shah Deniz Consortium, and the first pipeline to complete its Front End Engineering Design (FEED). Coupled with today’s announcement it demonstrates that we are in pole position to win the right to transport Caspian gas to Europe.”

Having submitted TPA applications to the Greek, Albanian and Italian national authorities in September 2011, TAP received its national exemptions in March 2013 under the Directive 2009/73/EC.

<strong>About the Trans Adriatic Pipeline (TAP) </strong>

TAP will transport natural gas from Azerbaijan to the most attractive markets in Europe.

The pipeline will connect with the Trans Anatolian Pipeline (TANAP) near the Turkish-Greek border at Kipoi, cross Greece and Albania and the Adriatic Sea, before coming ashore in Southern Italy.

TAP’s routing can facilitate gas supply to several South Eastern European countries, including Bulgaria, Albania, Bosnia and Herzegovina, Montenegro, Croatia and others. TAP’s landfall in Italy, the third largest gas market in Europe, provides multiple opportunities for further transport of Caspian natural gas to some of the largest European markets such as Germany, France, the UK, Switzerland and Austria.

Designed to expand the capacity from 10 to 20 bcm per year, TAP will open up the so-called Southern Gas Corridor, enhancing Europe's energy security by providing a new source of gas.

TAP’s shareholders are Axpo of Switzerland (42.5%), Norway’s Statoil (42.5%) and E.ON of Germany (15%). Shah Deniz Consortium members – BP, SOCAR and Total - have the option to join TAP, if it is selected in June 2013 as the gas transportation route to Europe, and they are currently funding the development of the TAP project.]]>7644http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7644Mon, 20 May 2013 00:00:00 +0100 This action is due to production deferment following a reported leak along the Eastern Gas Gathering System (EGGS-1) right-of-way (RoW) near Awoba in Rivers State. In line with safety precautions, we have shut down our Soku and Gbaran Ubie gas export via the EGGS1 pipeline.

Some 1.5 billion standard cubic feet of gas per day is currently impacted. For a limited time and subject to capacity limitations, we are able to export about 100-200MMscf/d from Soku via the GTS1.

<a href="http://www.euro-petrole.com/terminal-lng-de-bonny-island-l-87" target="blank" class="lien">See the site of NLNG terminal</a>]]>7643http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7643Mon, 20 May 2013 00:00:00 +0100
The total amount we and our partners invested in the 11th round was R$1,460.9 million, of which R$537.9 million were with our own funds, and R$923 million coming from partners. The outcome of the auction will also broaden the knowledge on the geology of sedimentary basins in the blocks that were acquired, with the drilling of wells and by acquiring large volumes of seismic data, thus increasing the chance of discovering new oil and gas accumulations. For this end, important partnerships were formed in all offshore blocks that were acquired.

Our strategy in the bid was successful, and was aligned with the objectives set out in our 2013-2017 Business and Management Plan, which is to incorporate new exploration areas for a continuous recomposition of our portfolio in order to ensure the volumes of oil and natural gas needed for the sustainability of the future production curve.]]>7642http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7642Mon, 20 May 2013 00:00:00 +0100 Sempra is planning an LNG export project at Cameron in Louisiana, U.S.A. A 100% subsidiary of Sempra, Cameron LNG LLC ("Cameron LNG"), currently owns and operates the Cameron LNG receiving terminal and plans to develop liquefaction facilities with the export capability of 12 million tonnes per annum (MTPA)(4 MTPAx3 trains). The total development cost is expected to be in the range of $ 9-10 billion. First LNG production is targeted in the latter half of 2017, after receiving related approvals including export license for Non-FTA countries by Department of Energy (DOE).

Based on the natural gas tolling liquefaction agreement, Mitsui will secure 4 MTPA of tolling capacity for 20 years (*). In addition, based on the joint venture agreement, Mitsui will acquire a 16.6% equity interest in Cameron LNG Holdings LLC, which will be established as a holding company of Cameron LNG (*). Other equity holders will be Sempra (50.2%), a joint venture between Nippon Yusen Kabushiki Kaisha and Mitsubishi Corporation (16.6%) and GDF Suez (16.6%).

Global demand for natural gas and LNG is expected to grow in the medium to long term. Mitsui already owns upstream shale interests in Marcellus and Eagle Ford areas which contribute to natural gas production in U.S.A. In addition, through the above mentioned agreements, Mitsui will contribute to stable LNG production as well as stable energy supply to the global market including Japan.


(*) Both the natural gas tolling liquefaction agreement and the joint venture agreement will become effective subject to issuance of export license for Non-FTA countries by DOE, construction permit by FERC and satisfaction of other condition precedents.

<a href="http://www.euro-petrole.com/terminal-lng-cameron-lng-l-940" target="blank" class="lien">See the site of Cameron LNG Terminal</a>]]>7641http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7641Mon, 20 May 2013 00:00:00 +0100
The Julia field is located in the Gulf of Mexico Walker Ridge area in approximately 7,000 feet (2,100 meter) water depth. FMC Technologies' scope of supply includes six subsea trees, a manifold and associated tie-in equipment.

"FMC Technologies is pleased to provide ExxonMobil with subsea systems for this offshore project," said Tore Halvorsen, FMC Technologies' Senior Vice President, Subsea Technologies. "We look forward to supporting ExxonMobil as they overcome the technological challenges of this ultra deepwater development."

<strong>About FMC Technologies</strong>
FMC Technologies, Inc. (NYSE: FTI) is a leading global provider of technology solutions for the energy industry. Named by FORTUNE® Magazine as the World's Most Admired Oil and Gas Equipment, Service Company in 2012, the Company has approximately 18,900 employees and operates 30 production facilities in 16 countries. FMC Technologies designs, manufactures and services technologically sophisticated systems and products such as subsea production and processing systems, surface wellhead systems, high pressure fluid control equipment, measurement solutions, and marine loading systems for the oil and gas industry.]]>7640http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7640Mon, 20 May 2013 00:00:00 +0100
DualEx Nyirseg Inc. (a wholly owned subsidiary of the Company) purchased the interest from Ascent Resources plc for cash consideration of €272,500 (approximately $360,000). The purchase increases DualEx’s interest in PetroHungaria to 70%. PetroHungaria operates the 43.38 km2 Penészlek II Mining Plot in northeast Hungary, which includes two producing natural gas wells. DualEx’s net share of Penészlek production is currently averaging 850 mcfe per day.

In Tunisia, DualEx reports that the Hydrocarbon Committee has formally approved a one-year extension to the initial term of the Bouhajla Permit, which will now expire on April 29, 2014. As previously announced, the Company and the Tunisian state oil company, Entreprise Tunisienne d'Activités Pétrolières (“ETAP”), applied for a one-year extension of the first exploration period of the Permit in February 2013.

Rig move and rig-up of the CTF-6 drilling rig is ongoing at the BHN-1 well site on the Bouhajla Permit. Drilling is anticipated to start immediately after rig-up is completed, and will be announced by the Company. The BHN-1 well will be drilled on the Bouhajla North prospect to a planned total depth of 2,545 metres in order to evaluate a Cretaceous Abiod target, which is analogous to the Sidi el Kilani field twenty-five kilometers to the east. The well is expected to take four to six weeks to reach total depth.

About DualEx Energy International Inc.
DualEx Energy International Inc. is an oil and gas exploration and production company with operations in Tunisia and Hungary. DualEx’s common shares trade on the TSX Venture Exchange under the symbol "DXE".]]>7639http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7639Mon, 20 May 2013 00:00:00 +0100
1. Client : Qatar Shell GTL Ltd.
2. Contract Period : 4 years + 1 year extension (as option)
3. Scope of Work : Engineering and project management
services including FEED and EPCm activities at Pearl GTL plant

Chiyoda has been continuously involved in numerous projects in Qatar including all 14 LNG trains, out of which Chiyoda executed the EPC work for 12 trains including the six world’s largest ones (7.8 million tons/year each). Chiyoda Almana currently has more than 500 experienced employees and has consistently provided “Project Lifecycle Engineering *3” for Qatari clients. This award follows long term service contracts previously awarded by RasGas, Qatargas and other companies.

Through this contract, which is in line with Qatar Shell’s commitment to support the social and economic pillars of the Qatar national vision 2030, Chiyoda group is aiming to contribute further to Qatari sustainable development. Chiyoda group, through its global operation network, intends to roll out its “Project Lifecycle Engineering” services in other countries including the Middle East and elsewhere while strengthening its regional business development.

(1) Chiyoda Almana was established by Chiyoda in March 2008 in collaboration with a local company
(Almana Group), as a Qatari local company providing full engineering services in Qatar.

(2) Chiyoda executed EPC work for the Feed Gas Preparation Works of the Pearl GTL plant in partnership with Hyundai Heavy Industries (HHI).

<a href="http://www.euro-petrole.com/raffinerie-pearl-gtl-de-ras-laffan-l-1585" target="blank" class="lien">See the site of Pearl GTL</a>]]>7638http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7638Mon, 20 May 2013 00:00:00 +0100
The Ceará basin is a Cretaceous rift basin with a proven oil source rock. The minimum work commitment program includes seismic surveys and the required exploration wells.

In Block 717, 3D seismic acquisition will be performed over 300 km2. In Block 665, located in an area where a large play has been identified, 3D seismic will likewise be conducted on 1000 km2 to assess its potential.

These new exploration licenses will play a key role in CEPSA’s strategy of expanding its upstream activities and diversifying its portfolio, and will strengthen and enhance its position in Latin America, representing a major opportunity and significant leap forward in offshore operations.

<strong>About Cepsa</strong>
CEPSA, 100% owned by IPIC, is an energy group with a workforce of nearly 12,000 employees, engaged in activities that span the entire oil value chain: exploration and production of oil and gas; refining, transportation and marketing of petroleum products and natural gas; biofuels; and electric power cogeneration and sales. CEPSA additionally has a world-class chemicals division that is tightly integrated with its oil refining segment, manufacturing and selling feedstock for the production of high value-added components chiefly used in making new-generation plastics and biodegradable detergents. Not only is CEPSA a major energy player in Spain, but it is also broadening its global portfolio of operations in countries such as Algeria, Brazil, Canada, Colombia, Panama, Peru and Portugal, selling its products around the world]]>7637http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7637Mon, 20 May 2013 00:00:00 +0100
Under the terms of the deal announced in August 2012, the assets include BP’s Carson, California refinery and related logistics and marketing assets in the region. Since that time, BP and Tesoro have been providing information to regulatory authorities to enable the parties to gain approval to complete the transaction for proceeds of approximately $2.5 billion.

“With FTC clearance, we have taken a significant step closer to completion of this sale and to the strategic refocusing of our U.S. fuels portfolio,” said Iain Conn, chief executive of BP’s global refining and marketing business. “I am very proud of the team’s work to achieve clearance of the sale and for consistently safe and high quality operations throughout the process. BP’s future U.S. fuels business soon will be firmly rooted around three, highly sophisticated northern refineries, which are crude feedstock-advantaged, and tied to strong marketing businesses.”

About BP in the US</strong>
BP has invested more in the United States over the last five years than any other oil and gas company. With more than $55 billion in capital spending between 2008 and 2012, BP invests more in the U.S. than in any other country. The company is the nation’s second largest producer of oil and gas, a major oil refiner and a leader in alternative energy sources. With 21,000 U.S. employees, BP supports nearly a quarter of a million domestic jobs through its business activities.

<strong>About Carson Refinery</strong>
The Carson Refinery is one of the largest on the U.S. West Coast, with a crude distillation capacity of 266,000 bpd. It became part of BP through the 2000 acquisition of ARCO. It employs over 1,100 staff and in total the divested business employs approximately 1,750 staff.
The transaction includes the refinery and integrated terminals and pipelines, as well as marketing agreements with about 800 retail sites in Southern California, Arizona and Nevada.
The refinery is located on 650 acres in Los Angeles County, near the Long Beach and Los Angeles Harbors. The refinery began operations in 1938. It processes crude oil from Alaska’s North Slope, the Middle East and West Africa. Processing equipment includes the largest fluid catalytic cracker in California, two cokers and distillate hydrocracking.
BP’s 51 percent interest in a nominal 400 megawatt cogeneration facility located at the refinery is included in the sale.
BP’s Wilmington Coke Calciner located about five miles from the refinery is also part of the sale. The plant occupies about 17 acres. The plant employs approximately 40 people and produces 350,000 metric tons of calcinated coke per year.
Logistics assets included in the sale include ownership of Berth 121 facility improvements and equipment, Marine Terminals 2 and 3 and the LA basin pipelines system that moves crude, products and intermediates to and from the refinery.
Terminals included in the sale are Carson Crude, East Hynes, West Hynes, Hathaway, Carson Products, Colton, Vinvale and San Diego.
BP is completing a number of major investments in its other US refineries, including a large investment program to transform its 413,000 bpd capacity Whiting, Ind., refinery to process heavy, sour crudes, expected to come on stream in the second half of this year; a recently-completed clean diesel upgrading project at its 234,000 bpd Cherry Point, Wash., refinery; and the recent start-up of a continuous catalytic reformer to the 160,000 bpd capacity Toledo, Ohio, refinery (a 50:50 joint venture with partner Husky Energy Inc.).
BP will continue to maintain a number of business interests in California, including a large ARCO retail and logistics presence in the northern part of the state. BP will also continue the distribution and marketing of lubricants through its Castrol brand and remain active in the California natural gas and power sector. In addition, BP will also continue to support the development of renewable energy sources in California through its Global Biofuels Technology Center in San Diego, and the Energy Biosciences Institute at UC Berkeley.

<a href="http://www.euro-petrole.com/raffinerie-de-carson-l-461" target="blank" class="lien">See the site of Carson Refinery</a>]]>7636http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7636Mon, 20 May 2013 00:00:00 +0100
The EIB will be financing various activities under the company’s wide-ranging RDI programme comprising i) the optimisation of natural gas transport; ii) improvement of energy efficiency in the oil refining process; iii) development and production of petrochemical derivatives; and iv) CO2 storage. The programme will also include the development of renewable and biofuel transport solutions.

The bulk of the planned activities under the RDI programme will be carried out at Repsol’s technology centre in Móstoles in Spain, in cooperation with universities and tech companies. The investments will be implemented over the period 2013-2016.

The investments financed by this loan meet the EU and EIB objectives of ensuring a sustainable, competitive and secure energy supply and fostering the energy efficiency and technological capacity of Europe’s businesses.]]>7635http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7635Mon, 20 May 2013 00:00:00 +0100
<strong>Reduced cycle time</strong>
The 3D Interpretation application makes it easy for teams to build, refine and complete their structural, stratigraphic and rock property models without leaving the Jason suite. Interpreters can visualize all of their subsurface data including wells, horizons, faults, seismic and rock property volumes. Tight integration with Jason’s deterministic and geostatistical product suite streamlines customers’ quantitative interpretation (QI) efforts, letting them spend more time interpreting and less time moving data around. This promotes faster, smoother workflows and reduces operating costs.

<strong>High-quality results </strong>
3D Interpretation complements the quantitative analysis and risk reduction techniques clients have come to value from Jason. Interpreters are able to deliver more accurate and reliable results based on all available subsurface information. Within the Jason suite, QI teams can integrate structural, stratigraphic and rock property information into a detailed reservoir model, and then QC their results. This process helps asset teams reduce project risk by continuously improving the quality and reliability of their geologic models.

<strong>Improved project economics</strong>
High-quality 3D Interpretation, coupled with superior reservoir characterization technology, helps customers mitigate risk during field development planning. With the integrated suite of Jason products, oil companies are better able to select the best well locations. Ultimately, greater understanding and predictability of the subsurface helps customers maximize production while minimizing cost.

Sophie Zurquiyah, Senior Executive Vice President, Geology, Geophysics &amp; Reservoir, CGG, said: “3D Interpretation is another example of Jason’s commitment to developing software technology that meets paramount client concerns for efficiency, accuracy and usability while extending capability. This new tool leverages Jason’s traditional strength in inversion by adding integrated volume visualization and interpretation capabilities. Its launch also marks further progress in CGG’s strategy to expand its offering in the interpretation market and enable our clients to leverage better reservoir models from their seismic investments.”

<strong>About CGG</strong>
CGG (www.cgg.com) is a fully integrated Geoscience company providing leading geological, geophysical and reservoir capabilities to its broad base of customers primarily from the global oil and gas industry. Through its three complementary business divisions of Equipment, Acquisition and Geology, Geophysics &amp; Reservoir (GGR), CGG brings value across all aspects of natural resource exploration and exploitation.
CGG employs 9,800 people around the world, all with a Passion for Geoscience and working together to deliver the best solutions to its customers.]]>7634http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7634Sun, 19 May 2013 00:00:00 +0100
Pour Pierre MOSCOVICI, ministre de l'Économie et des Finances et Delphine BATHO il s'agit d'une réforme majeure réalisée par le gouvernement pour protéger le pouvoir d'achat des consommateurs, assurer la transparence des prix au regard des coûts d'approvisionnement et mettre fin à des contentieux à répétition.

Le décret publié ce jour prévoit :
- un audit annuel des coûts d'approvisionnement et hors approvisionnement des fournisseurs par la Commission de régulation de l'énergie,
- la fixation par arrêté de la nouvelle formule au premier juillet de chaque année par les ministres chargés de l'économie et de l'énergie, après avis de la Commission de régulation de l'énergie,
- l'évolution à une fréquence mensuelle des tarifs en fonction de la formule,
- une clause de sauvegarde : en cas d'augmentation exceptionnelle des prix, le Premier ministre peut, après avis de la Commission de régulation de l'énergie, s'opposer par décret au mouvement automatique résultant de la formule, et fixer de nouveaux barèmes.

Cette réforme a déjà permis 6 mois consécutifs sans hausse des prix et la baisse 5 mois sur 6. Au premier trimestre, c'est environ 3 € par mois économisés sur la facture d'un ménage se chauffant au gaz.

La Commission de régulation de l'énergie a d'ores-et-déjà réalisé l'audit des coûts d'approvisionnements de GDF Suez. Elle a validé la formule tarifaire pour 2012 et celle en vigueur au début de l'année 2013. Elle a confirmé la nécessité d'une évolution de la formule avant la fin de l'année 2013 pour tenir compte des évolutions programmées de certains contrats de long terme au second semestre et des renégociations en cours.

Ces évolutions devraient conduire à une nouvelle augmentation de la part d'indexation spot dans la formule, qui pourrait atteindre 40 % au lieu de 35,9 % aujourd'hui.

<a href="http://www.euro-petrole.com/re_02_details_article.php?idArticle=517" target="blank" class="lien">Voir le décret du 16 mai 2013</a>]]>7633http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7633Fri, 17 May 2013 00:00:00 +0100
Située sur le site du terminal méthanier de Sempra Energy à Hackberry, cette usine sera constituée de 3 trains de liquéfaction d’une capacité de 12 millions de tonnes de gaz naturel liquéfié (GNL) par an et sera exploitée par Cameron LNG.

Aux termes de cet accord, GDF SUEZ, Mitsubishi et Mitsui vont acquérir une participation de 16,6 % chacun dans le terminal existant et dans le projet de liquéfaction, Sempra Energy conservant 50,2 %.

Comme annoncé l’an dernier, GDF SUEZ a également signé avec Sempra Energy un contrat de service de liquéfaction pour une durée de 20 ans. GDF SUEZ, Mitsubishi et Mitsui ont souscrit la totalité de la capacité de liquéfaction des 3 trains de l’usine. GDF SUEZ aura ainsi accès à une capacité de 4 millions de tonnes de GNL par an, qui seront exportés vers les marchés GNL du Groupe.

Jean-Marie Dauger, Directeur général adjoint de GDF SUEZ, en charge de la branche Global Gaz &amp; GNL, a déclaré : « Par son entrée dans le projet Cameron LNG aux côtés de partenaires solides et expérimentés, GDF SUEZ, acteur majeur du GNL dans le monde, entend contribuer de façon décisive à l’émergence d’une nouvelle source de GNL aux Etats-Unis. Le projet Cameron LNG permettra de diversifier et d’accroître le portefeuille de GNL du Groupe ainsi que sa flexibilité, pour alimenter ses marchés actuels ou futurs dans les zones en forte croissance. »

Les accords de tolling et de joint venture restent soumis à la décision finale d’investissement de chacune des parties, à la finalisation de toutes les autorisations et à la sécurisation du financement, qui devraient intervenir début 2014, ainsi qu’aux autres conditions suspensives courantes. La nouvelle usine GNL devrait entrer en production fin 2017. L’an dernier, Cameron LNG a obtenu du ministère américain de l’Energie l’autorisation d’exporter jusqu’à 12 millions de tonnes par an de GNL, produit localement, vers tous les pays actuels et futurs avec lesquels les États-Unis ont des accords de libre échange1.

GDF SUEZ est l’un des acteurs majeurs dans le domaine du GNL à travers le monde et le premier importateur de GNL en Europe. Son portefeuille de 16 millions de tonnes par an, provenant de 6 pays différents, est le troisième mondial. Le Groupe exploite une flotte de 17 méthaniers et affiche une présence importante dans des terminaux de regazéification à travers le monde.
1 L’autorisation d’exporter du GNL vers des pays avec lesquels les États-Unis n’ont pas signé d’accord de libre échange a fait l’objet d’une demande et reste encore soumise à une décision ultérieure du ministère de l’Energie américain (DOE). A ce jour, un seul projet GNL a obtenu toutes les autorisations d’exportation aux États-Unis.

<strong>A propos de GDF SUEZ</strong>
GDF SUEZ inscrit la croissance responsable au cœur de ses métiers (électricité, gaz naturel, services) pour relever les grands enjeux énergétiques et environnementaux : répondre aux besoins en énergie, assurer la sécurité d’approvisionnement, lutter contre les changements climatiques et optimiser l’utilisation des ressources. Le Groupe propose des solutions performantes et innovantes aux particuliers, aux villes et aux entreprises en s’appuyant sur un portefeuille d’approvisionnement gazier diversifié, un parc de production électrique flexible et peu émetteur de CO2 et une expertise unique dans quatre secteurs clés : le gaz naturel liquéfié, les services à l’efficacité énergétique, la production indépendante d’électricité et les services à l’environnement. GDF SUEZ compte 219 300 collaborateurs dans le monde pour un chiffre d’affaires en 2012 de 97 milliards d’euros. Coté à Paris, Bruxelles et Luxembourg, le Groupe est représenté dans les principaux indices internationaux : CAC 40, BEL 20, DJ Euro Stoxx 50, Euronext 100, FTSE Eurotop 100, MSCI Europe, ASPI Eurozone, Vigeo World 120, Vigeo Europe 120 et Vigeo France 20.

<a href="http://www.euro-petrole.com/terminal-lng-cameron-lng-l-940" target="blank" class="lien">Voir le site de Cameron LNG</a>]]>7631http://www.euro-petrole.com/ne_03_actualite_i_details.php?idNews=7631Thu, 16 May 2013 00:00:00 +0100
The customer has chosen the most fuel-efficient and low-emission propulsion solution available in the market today for their two recently ordered LNG (liquefied natural gas) carriers. It consists of the ME-GI engine from MAN Diesel &amp; Turbo and the fuel gas compressor system Laby®-GI from Burckhardt Compression. The two gas carriers have each a capacity of 170’000 cubic meters.

The fully balanced compressor system will inject boil-off gas into the ME-GI dual-fuel two-stroke engine. The ME-GI system can alternatively be operated with ecological natural gas or heavy fuel oil. Thanks to the reliquefaction option, it is the most flexible propulsion solution in the LNG carrier market and operates with a minimum of emissions. Stricter environmental regulations and increasing fuel oil prices demand such new propulsion solutions.

Marcel Pawlicek, CEO at Burckhardt Compression states: “With this first order we have achieved a major milestone. It reinforces our aim to achieve together with MAN Diesel &amp; Turbo a significant market share for the ME-GI propulsion system for LNG carriers.”

MAN Diesel &amp; Turbo has built up a strong relationship with the Swiss reciprocating compressor manufacturer Burckhardt Compression over the past years to fine-tune the engine and fuel gas compressor system. This has produced a noncomplex compressor system with a sophisticated control system and lowest demands on the crew for operating and maintenance. Based on proven technology, the Laby®-GI Compressor provides fuel gas to the propulsion system with highest efficiency at lowest operating cost. The fully balanced design, resulting in the elimination of unbalanced moments and forces, makes this type of compressor the perfect solution in marine environments. Burckhardt Compression has decades of experience in the field of LNG and LPG (liquefied petroleum gas).

<strong>About Burckhardt Compression</strong>
Burckhardt Compression is one of the worldwide market leaders in the field of reciprocating compressors and the only manufacturer that offers a complete range of Laby(labyrinth piston), Process Gas, and Hyper Compressors. The compressors are used to compress, cool or liquefy gases. Burckhardt Compression’s customers include multinational companies active in the chemical, petrochemical, refinery, industrial gas and gas transport and storage industries. With the leading compressor technology, the high-quality compressor components and the comprehensive range of services Burckhardt Compression supports its customers in their effort to minimize the life cycle costs of their reciprocating compressor systems. ]]>7630http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7630Thu, 16 May 2013 00:00:00 +0100
Dix ans après Girassol, ce deuxième prix pour Pazflor témoigne de la reconnaissance du monde pétrolier pour l’expertise de Total dans l’offshore profond.
En une décennie seulement, Total a démontré son excellence dans ce secteur avec de nombreux projets développés à travers le monde. L’offshore profond est aujourd’hui un de nos 4 principaux secteurs de croissance faisant ainsi partie intégrante de la stratégie de l’EP.

<strong>A propos du projet Pazflor</strong>
La stratégie du projet PAZFLOR a été de constituer une équipe de gestion de projet intégrée, pluridisciplinaire et autonome. La plupart de ses membres étaient basée dans les locaux des contracteurs ou sur sites. Elle avait la charge de l’ensemble des activités, depuis les géosciences jusqu'aux opérations.
Pazflor comportait des défis importants qui lui ont valu de remporter ce prix :
- défis technologiques avec un système de séparation gaz/liquides pour produire économiquement deux types d'huile à partir de trois réservoirs Miocène et d’un réservoir Oligocène. Ce système en fond de mer constituait une première mondiale.

- défis en termes de management de projet du fait du gigantisme de Pazflor : une zone de développement de 600 km2 ; le plus grand FPSO jamais construit au monde ; 32 millions d’heures travaillées, jusqu’à 4500 personnes ayant travaillé sur le projet dans le monde ; des contraintes strictes en termes de HSE, de planning, de budget, de qualité…
Pazflor est aussi un très bel exemple de collaboration entre une major et une NOC, Sonangol, qui a contribué de manière significative au développement de la main-d'œuvre locale.
La qualité de la gestion du projet a permis au développement de Pazflor d'être achevé dans le budget et même de démarrer plus tôt que prévu, en août 2011.

<strong>A propos de l'OTC</strong>
Fondé en 1969, l'Offshore Technology Conference (OTC), est le congrès majeur du secteur pétrolier.
L'OTC a lieu chaque année à Houston et attire quelques 80 000 personnes venant de plus de 110 pays.
L’OTC a pour objectif de mettre en avant les avancées technologiques, les bonnes pratiques, la sécurité et les aspects environnementaux relatifs au domaine de l'offshore.
Cette année, cette conférence se déroule du 6 au 9 mai 2013.]]>7629http://www.euro-petrole.com/ne_02_actualite_f_details.php?idNews=7629Thu, 16 May 2013 00:00:00 +0100
Le projet comprend l’installation d’un train d’envergure mondiale de 431 kilotonnes par an d’une unité de polyéthylène à basse densité linéaire (LLDPE). NOVA Chemicals augmentera la capacité totale de polyéthylène de son site de Joffre d’environ 40 % et utilisera la capacité actuelle en éthylène de son site.

En plus de l’ingénierie de détail et de la fourniture des équipements de la nouvelle section de réaction, de la section d’extrusion et de la section de chargement des wagons, Technip modifiera les systèmes de purification existants et concevra également les unités hors site, les utilités, les interconnexions et d’autres unités de support pour l’usine.

Les centres opérationnels de Technip à Houston (Texas), Calgary (Canada) et Chennai (Inde) réaliseront ce contrat. Le travail sur cette phase du projet a débuté fin 2012. L’ingénierie devrait s’achever en 2014 et le démarrage des systèmes fin 2015.

David Dickson, Senior Vice President de Technip en Amérique du Nord, a déclaré : « Cette opportunité permettra à Technip de poursuivre la relation avec son client clé NOVA Chemicals. Nous sommes ravis d’avoir remporté ce contrat après avoir réalisé la pré ingénierie d’avant-projet détaillé (pré-FEED) et le FEED de ce projet d’extension. Ce nouveau contrat consolide la position de leader du Groupe dans la réalisation de projets de polyoléfines ainsi que sa position en tant que contracteur EPC de choix en Amérique du Nord et à travers le monde. »

* Le cœur d’activité de NOVA Chemicals est la production et la commercialisation de plastiques et de produits chimiques. Le site de Joffre près de Red Deer (Alberta, Canada) est l’un des plus grands complexes d’éthylène et de polyéthylène au monde. Le site comprend cinq unités de fabrication détenues par NOVA Chemicals, trois pour la production d’éthylène et deux pour la production de polyéthylène.

<strong>A propos de Technip</strong>
Technip est un leader mondial du management de projets, de l’ingénierie et de la construction pour l’industrie de l’énergie.

Des développements Subsea les plus profonds aux infrastructures Offshore et Onshore les plus vastes et les plus complexes, nos 36 500 collaborateurs proposent les meilleures solutions et les technologies les plus innovantes pour répondre au défi énergétique mondial.

Implanté dans 48 pays sur tous les continents, Technip dispose d’infrastructures industrielles de pointe et d’une flotte de navires spécialisés dans l’installation de conduites et la construction sous-marine.]]>