Shin J.,Korea Institute of Geoscience and Mineral Resources |
Shin C.,Seoul National University |
Calandra H.,TOTAL Exploration and Production
Journal of Applied Geophysics | Year: 2016
Laplace-domain waveform inversion reconstructs long-wavelength subsurface models by using the zero-frequency component of damped seismic signals. Despite the computational advantages of Laplace-domain waveform inversion over conventional frequency-domain waveform inversion, an acoustic assumption and an iterative matrix solver have been used to invert 3D marine datasets to mitigate the intensive computing cost. In this study, we develop a Laplace-domain waveform modeling and inversion algorithm for 3D acoustic-elastic coupled media by using a parallel sparse direct solver library (MUltifrontal Massively Parallel Solver, MUMPS). We precisely simulate a real marine environment by coupling the 3D acoustic and elastic wave equations with the proper boundary condition at the fluid-solid interface. In addition, we can extract the elastic properties of the Earth below the sea bottom from the recorded acoustic pressure datasets. As a matrix solver, the parallel sparse direct solver is used to factorize the non-symmetric impedance matrix in a distributed memory architecture and rapidly solve the wave field for a number of shots by using the lower and upper matrix factors. Using both synthetic datasets and real datasets obtained by a 3D wide azimuth survey, the long-wavelength component of the P-wave and S-wave velocity models is reconstructed and the proposed modeling and inversion algorithm are verified. A cluster of 80 CPU cores is used for this study. © 2016 Elsevier B.V.
Turlan F.,TOTAL Exploration and Production |
Audibert-Hayet A.,TOTAL Exploration and Production
Society of Petroleum Engineers - Arctic Technology Conference 2012 | Year: 2012
TOTAL Exploration & Production has been active in cold environments since 1970 (i.e. drilling in the Arctic Islands in Canada) and has been operating the Russian Kharyaga field since 1999. For its first experiences in those challenging conditions, TOTAL applied its internal rules and specifications that were not aimed at this kind of environments but to "classic" prospects, the main assets being in the Guinea Golf, in the North Sea, the Middle East and in South East Asia. As the prospects and TOTAL'S portfolio have developed in areas where temperatures are below -15°C, such as Kashagan field in Kazakhstan or Yamal in Russia, an "Extreme Cold" taskforce was put together several years ago. The aim is to gather feedbacks from the past and to centralize the Research & Development activities to look for innovative solutions for the future and on-going projects. The workgroup is organized around several panels, one of those being the Health and Safety aspects for the operations in Extreme Cold conditions. From partnership through JIPs, internal research and workshops with affiliates (mainly in Norway, Russia or Canada), and projects teams, it has been decided to produce internal guidelines in order to define and harmonize the practices, acknowledging that each field has its own meteorological constraints, and to gather the results from the multiple actions carried out by TOTAL headquarters or affiliates. The methodology and the risk analysis performed to obtain a common technical basis will be here presented. Copyright 2012, Offshore Technology Conference.
Thibaut E.,Total Exploration and Production |
Meyer E.,Total Exploration and Production |
Rambaldi E.,Total Exploration and Production
Proceedings of the Annual Offshore Technology Conference | Year: 2010
Work is currently ongoing in the offshore oil & gas industry to develop subsea processing systems supplying multiple electrical consumers, over long step-outs and in deep waters. To meet the technical challenges of these developments, new subsea electrical power transmission and distribution architectures have to be developed. This paper gives an overview of possible electrical power transmission and distribution architectures. It addresses the main technical challenges and present limitations, describes the system approach and gives an operator's viewpoint as to the way forward. Copyright 2010, Offshore Technology Conference.
Thibaut E.,TOTAL Exploration and Production |
Leforgeais B.,TOTAL Exploration and Production
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference 2012, ADIPEC 2012 - Sustainable Energy Growth: People, Responsibility, and Innovation | Year: 2012
Martin Linge offshore gas field (formerly named Hild) is located on the Norwegian sector of the North Sea, southwest from Oseberg. The field development comprises a platform with a jack up rig and Floating Storage Offloading unit. This offshore development will be supplied with electric power from shore, through a High Voltage AC submarine cable. With a step out distance of 170km and a design power of 55MW, this will be the world's longest AC submarine cable power supplying an entire offshore Oil and Gas platform from the shore. This paper presents the Martin Linge project, it discusses the criteria considered to select a power from shore instead of an offshore Gas Turbine power plant which is the current practice in the offshore Oil and Gas industry. And since in a first approach, for such long step-out distance, the choice of power from shore would be to select a DC transmission line, the paper discusses the design, system approach and main technical challenges of this long step-out AC transmission development. Finally, the paper gives an operator's viewpoint as to the way forward. Copyright 2012, Society of Petroleum Engineers.
Yan R.,University of California at Santa Cruz |
Guan H.,Total Exploration and Production |
Xie X.-B.,University of California at Santa Cruz |
Wu R.-S.,University of California at Santa Cruz
Geophysics | Year: 2014
Due to incomplete aperture coverage and complex overburden structures, the migration process cannot provide a trueamplitude image even though a true-amplitude propagator is used. Amplitude compensation based on source-side illumination ignores the aperture effects on the receiver side, and it may fail to recover the true-reflection/scattering strength of a geologic structure from the image. The structural dip largely controls if the wave incident on the structure can be reflected back and received by the acquisition aperture, so it should be taken into account in removing the acquisition effects from the migration image. We derived a dip-angle domain amplitude correction from the resolution theory. The stacked migration image created by reverse time migration was decomposed into common dip images, which were compensated individually by the corresponding amplitude correction factor. Then, we summed up the corrected images to form a final image. To construct the amplitude correction factor, we generated a monofrequency Green's function at the shot/geophone location and further decomposed it into incident/scattered plane waves. They were combined based on Snell's law to construct correction factors for different dips. The final amplitude correction factor was formed by visiting all the shotgeophone pairs in the observation system. We devised efficient algorithms to make the amplitude correction more practical. We evaluated two numerical experiments, a five-layer model and the SEG/EAGE salt model, in which the amplitude correction led to a scalar/pressure image with an amplitude better matching the true impedance contrasts of subsurface structures, especially in areas with steep dips and in subsalt regions. © 2014 Society of Exploration Geophysicists.
Khan F.,Total Exploration and Production |
Goujard V.,Total Exploration and Production |
Tincelin P.H.,Total Exploration and Production |
Tison M.,Total Exploration and Production |
And 2 more authors.
SPE Economics and Management | Year: 2012
Capitalizing on early successes in advanced well control and realtime monitoring, Total Exploration and Production has engaged in a major "digital-field" initiative. Combining both proven and leading-edge technologies, the field-monitoring template is providing a powerful tool for well and facilities performance monitoring and optimization. This paper presents the concept of the WPM module, and the early results of its pilot application whose implementation began in 2009 at the Girassol field located offshore Angola. The WPM module constitutes an integrated real-time monitoring solution for subsea installations, from reservoir inflow to receiving facilities. Proposing advanced features (e.g., a common asset model, a business orchestrator, and a Web-based interface), the tool provides remote access to timely and quality field data, improves communication and collaboration between offshore and onshore, and provides support by specialists from explorationand-production headquarters. Functional capabilities include data validation, virtual metering, wells and networks modeling, smart alarming, and production optimization. Specific workflows have also been defined to sustain continuous updating of the models to match observed field behavior. This paper illustrates the benefits of the WPM solution in terms of improved production and enhanced well diagnosis. It also reviews the organizational challenges associated with such a project and discusses the key factors ensuring successful implementation and good support from on-site teams. WPM brings forth a new approach for the intelligent surveillance of complex subsea-production systems. Well performance and production and reservoir teams have gained benefit from such a tool. Pertinent information is delivered to the right people in real time, enabling instant diagnosis and minimization of production shortfalls. In addition, the online simulator supports the continuous optimization of the field throughput by real-time integration of changing well behavior or production constraints. Copyright © 2012 Society of Petroleum Engineers.
Terentyev A.,Total Exploration and Production |
Fokin S.,Total Exploration and Production
GeoInformatics 2013 - 12th International Conference on Geoinformatics: Theoretical and Applied Aspects | Year: 2013
This paper gives brief overview of TOTAL's approach to 2G data management and describes an in-house solution developed to cover the needs of specialists.
Bordmann V.,TOTAL Exploration and Production
Society of Petroleum Engineers - SPE International Conference on Health, Safety and Environment in Oil and Gas Exploration and Production 2010 | Year: 2010
With Host Countries stepping up their demands and expectations in terms of local content, defining its perimeter and boundaries has created some confusion among the industry. It becomes a challenge for IOCs/NOCs to agree on its definition, perimeter, and hence on its indicators to measure it. This proposed paper will present a possible perimeter for local content development initiatives and suggest key performance indicators. Local content -aimed at enhancing skills, developing suppliers and infrastructures of Host Countries in connection with field development and production projects -now occupies a predominant place in the oil & gas producing countries. Usually measured as a percentage of investment, of man hours, of weight of equipment manufactured, or of jobs created and industrial bases used, local content concerns industrial capacities as much as human resources. IOC/NOC operators therefore act simultaneously on multiple levers to obtain progress on this front: training the country's technicians and managers, hiring local staff, stimulating the networks of SME and pre-qualifying local companies. This proposed paper is based on a definition of local content applied by TOTAL for its oil & gas development projects. It is also based on a methodology applied by TOTAL to measure local content for its oil & gas development projects. The main application of the information provided in the proposed paper is to provide the industry with one way of defining and measuring local content, which is not always formalised. Case studies will not be presented in this paper, only the methodology. Indeed, when it comes to benchmark local content of different oil & gas development project, it is rarely possible to do it, due to different definition / perimeters, and absence of local content indicators. Copyright 2010, Society of Petroleum Engineers.
Bordmann V.,TOTAL Exploration and Production |
Obembe O.,TOTAL E and P Nigeria |
Longuet L.,TOTAL E and P Indonesia
Society of Petroleum Engineers - SPE International Conference on Health, Safety and Environment in Oil and Gas Exploration and Production 2010 | Year: 2010
With Host Countries stepping up their demands and expectations in terms of local content, identifying and developing local capacity building initiatives becomes paramount for IOC/NOCs. This paper presents a process for identifying and developing local content initiatives, in order to achieve challenging local content development objectives and hence increase the acceptability of IOC/NOC operators. Local content -aimed at enhancing skills, developing suppliers and infrastructures of Host Countries in connection with oil & gas field development and production projects -now occupies a predominant place in the oil & gas producing countries. In a competitive context, local content becomes an important - not to say essential - criterion in securing new permit awards or obtaining approval for oil & gas field development plans. It appears paramount to build up a strong industrial fabric and have qualified manpower and contractors. It is all the more important that after the appraisal-development phases, the operator then requires skilled local / national personnel to produce the oil and/or gas fields for a several decades. This paper describes the process and illustrates it with case studies, i.e. best practices in identifying and developing local capacity building initiatives. These case studies mainly highlight education initiatives and innovative supplier development initiatives, the latter being suppliers of goods but also suppliers of highly technical services like front end engineering and design. This paper is based on best practices applied in the category of Corporate Social Responsibility. Illustrative data include case studies and lessons learnt from local capacity building initiatives implemented in various countries, mainly on the African continent (Nigeria), in Asia (Indonesia) and also worldwide through a specific higher education initiative. The main application of the information provided in this paper is to help IOC/NOC operators to build local content development initiatives, in both education and supplier development. Copyright 2010, Society of Petroleum Engineers.
Banner B.,TOTAL Exploration and Production |
Pourcel P.,TOTAL Exploration and Production |
Brown A.,TOTAL Exploration and Production
Society of Petroleum Engineers - SPE/APPEA Int. Conference on Health, Safety and Environment in Oil and Gas Exploration and Production 2012: Protecting People and the Environment - Evolving Challenges | Year: 2012
Lifting above or close to live hydrocarbon process plant or pipelines has long been an emotive subject. Managing such lifting is a fundamental part of the safe operation of the concerned production facilities. Lifting above live plant or lines can be encountered during normal production operations and also simultaneous operations for construction and production or drilling and production activities. Much of the time, with good preparation and planning, such lifts can be performed during planned shutdowns, therefore removing the 'live plant' hazard. However there are occasions when shutting down and depressurizing the plant or lines close to or under the lift path is not always perceived as possible. Based on this, a need was identified for a means to allow personnel to perform an appropriate level of assessment to aid in the decision making process regarding whether or not to allow such lifts. This paper presents the basis of a calculation tool developed to help determine whether or not a lift can be carried out over unprotected plant or lines in a consistent manner and which will give users confidence in the results generated. The tool calculates the potential impact energies of a dropped load and subsequent damage based on a percentage of indentation to a pipe or vessel diameter. This is derived from inputs by the user in terms of load shape, mass and potential drop height. Thereafter, depending on the plant or line types selected, the tool will advise whether or not the lift can be considered as acceptable providing that other criteria have been complied with. Clearly the final decision as to whether to lift above live plant or lines will be made by a team of appropriately qualified personnel. The benefits to be derived from the introduction of this tool include reduced uncertainty over whether or not such lifting is feasible and it should also reduce the number of enforced shutdowns and restarts, especially for smaller, repetitive types of lifts. Copyright 2012, SPE/APPEA International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production.