Gotowa bibliografia na temat „Temisflow”

Comprehensive interpretation of the results for regional seismic operations and reinterpretation of archived seismic data, their correlation with the drilling data of more than 30 deep wells, including Severo-Novoborsk parametric well, made it possible to clarify the structural maps and thickness maps of all seismic facies structures developed in the territory and water area in the junction of the north of Izhma-Pechora depression and Malozemelsko-Kolguevsk monocline of Timan-Pechora oil and gas province. Data obtained were used at basin modeling in TemisFlow software in order to reconstruct the conditions of submersion and transformation of organic substance in potential oil and gas bearing formations. Modeling made it possible to get an idea of ​​the time and conditions for the formation of large zones of possible hydrocarbons accumulation, to establish space-time connections with possible sources of generation, to identify the directions of migration and on the basis of comparison with periods of intense generation, both from directly located within the operation area and outside them (taking into account possible migration), to identify zones of paleoaccumulation of oil and gas. Work performed made it possible to outline promising oil and gas accumulation zones and identify target objects for further exploration within the site with an ambiguous forecast and lack of industrial oil and gas potential.

Abstract The ongoing exploration activities at the Pelotas basin of Brazil uncover some missing gaps in the existing wells for hydrocarbon accumulation prediction. Therefore, there is a need to further investigate the petroleum system of the basin, especially the organic facies, variations and distributions of the effectiveness of potential source rock. The adjacent basin, Santos basin is currently producing oil and gas fields will be used as the analogs to the Pelotas Basin. The aims of this research are to justify the presence of geological elements and processes of the petroleum system of the Pelotas Basin and to evaluate the potential of hydrocarbon prospectivity for exploration and exploitation of the basin. Two – dimensional basin modelling using TemisFlow will be used in this study. Hydrocarbon generation from the Turonian and Ypresian to Bartonian source rock started during Late Eocene. Visible Hydrocarbon migration can be seen from the Hydrocarbon saturation model. Hydrocarbon migration for Turonian source rock occurred during Early Miocene while for Ypresian to Bartonian, hydrocarbon migrate during Middle Miocene. Peak hydrocarbon expulsion reached during Middle Miocene for Turonian source rock and Ypresian to Bartonian source rock. Based on modelling result, hydrocarbon accumulation can be seen in Upper slope Early Miocene Sandstone, Early Miocene turbiditic sandstone and Early Oligocene turbiditic sandstone. Hydrocarbon composition in Early Miocene turbiditic sandstone and Upper Oligocene sandstone is mainly hydrocarbon liquid while for Early Miocene sandstone, the hydrocarbon composition is mix of hydrocarbon liquid and gas. Based on the prediction of source facies distribution, thermal maturity assessment, and migration and trapping mechanism, the oil and gas pool can be proposed for the future exploration and exploitation in the Pelotas Basin, offshore Brazil.

Faults are complex geological features acting either as permeability barrier, baffle or drain to fluid flow in sedimentary basins. Their role can be crucial for over-pressure building and hydrocarbon migration, therefore they have to be properly integrated in basin modelling. The ArcTem basin simulator included in the TemisFlow software has been specifically designed to improve the modelling of faulted geological settings and to get a numerical representation of fault zones closer to the geological description. Here we present new developments in the simulator to compute fault properties through time as a function of available geological parameters, for single-phase 2D simulations. We have used this new prototype to model pressure evolution on a siliciclastic 2D section located onshore in the Niger Delta. The section is crossed by several normal growth faults which subdivide the basin into several sedimentary units and appear to be lateral limits of strong over-pressured zones. Faults are also thought to play a crucial role in hydrocarbons migration from the deep source rocks to shallow reservoirs. We automatically compute the Shale Gouge Ratio (SGR) along the fault planes through time, as well as the fault displacement velocity. The fault core permeability is then computed as a function of the SGR, including threshold values to account for shale smear formation. Longitudinal fault fluid flow is enhanced during periods of high fault slip velocity. The method allows us to simulate both along-fault drainages during the basin history as well as overpressure building at present-day. The simulated pressures are at first order within the range of observed pressures we had at our disposal.

Whether or not the tight oil in the Triassic Yanchang Formation of the Ordos Basin is controlled by structural factors is a controversial issue, the relationship between the structural factors of the strata and the distribution of tight oil is limited to the study of current structures. The traditional view is that structural factors have no obvious control over the formation and distribution of the oil reservoir. Taking the Chang 8 member of the Triassic Yanchang Formation in the Ordos Basin as an example, this paper studies respectively the burial of strata-hydrocarbon generation history of the individual well and the structural evolution history of strata in the basin by using software tools of the Genex burial-hydrocarbon generation history restoration and TemisFlow evolution of stratigraphic structures. It is considered that the hydrocarbon generation period of the source rock of the Triassic Yanchang Formation in the Ordos Basin is from early Middle Jurassic to end of Early Cretaceous. By reconstructing the evolution and structure of the Chang 8 member during the hydrocarbon accumulation period, combined with a comprehensive analysis on the distributional characteristics of the Chang 8 oil reservoir, we found the palaeoslopes and palaeohighs of the Chang 8 reservoir to represent areas in which tight oils were distributed. Palaeo-structural characteristics of the target layer exhibit control over the Chang 8 reservoir. The new theory underlying tight oil exploration, which is based on the recovery of the palaeogeomorphology of the target layer during the hydrocarbon generation period, incorporates the vital roles of key controlling factors over tight oil accumulation, so that the mind-set on tight oil exploration in the Ordos Basin has evolved.

Abstract Overpressure and underpressure in the basin are mainly developed due to the disequilibrium compaction between the pore fluids and overburden pressure, and the heat flow/geothermal gradient in the rocks, leading to serious hazards in drilling operations due to the catastrophic well blowouts. Although some techniques have been used to explain the pore pressure mechanisms, there are still some missing gaps in the prediction. Basin modeling software is a very powerful tool as it incorporates various physical phenomena and can simulate the geological history of a sedimentary basin. Thus, a two-dimensional basin modeling software – TemisFlow, was used in the study. The present study was conducted at the Pelotas Basin, Brazil with the aims of (1) to build and run scenario test for pore pressure prediction of the Pelotas Basin, Brazil, (2) to identify the factors that control the pressure development, (3) to test the sensitivity of the parameters that control the pressure distribution, and (4) to evaluate the pressure distribution and pattern in the study area. The temperature model simulated by the software is calibrated with the field data provided in the well log as field pressure data is not provided. Nevertheless, calibration still can be done as the temperature at present and during the basin evolution is one of the parameters to pressure calculation in the model. Generally, the results show abnormal pressure zones are developed only in lower permeability of lithology – shale. Based on the simulations scenarios tested, the presence and generation of hydrocarbon in the Pelotas Basin also contribute a little to the development of overpressure in the basin. Based on the basin modeling results, the main overpressure mechanism in Pelotas Basin is still mainly due to compaction disequilibrium.

For more than twenty years, IFP Energies Nouvelles has been developing the thermodynamic library Carnot. While devoted to the origin of the oil and gas industry, Carnot is now focused on applications related to the new technologies of energy for an industry emphasizing decarbonization and sustainability, such as CCUS, biomass, geothermal, hydrogen, or plastic and metal recycling. Carnot contains several dozens of predictive and correlative thermodynamic models, including well-established and more recent equations of state and activity coefficient models, as well as many specific models to calculate phase properties. Carnot also contains a dozen flash algorithms making possible the computation of various types of phase equilibrium, including not only two-phase and three-phase fluid equilibria but also configurations with reactive systems and with solid phases such as hydrates, wax, asphaltene, or salts. The library Carnot has a double role: first, it is a standalone toolbox for thermodynamic research and development studies. Coupled with an optimization tool, it allows to develop new thermodynamic models and to propose specific parameterizations adapted to any context. Secondly, Carnot is used as the thermodynamic engine of commercial software, such as Carbone™, Converge™, TemisFlow™, CooresFlow™ or Moldi™. Through this software, several hundreds of end-users are nowadays performing their thermodynamic calculations with Carnot. It has also been directly applied to design industrial processes such as the DMX™ process for CO2 capture, the ATOL® and BioButterFly™ solutions for bio-olefins production, and Futurol™ and BioTFuel™ for biofuels production. In this context, this article presents some significant realizations made with Carnot for both R&D and industrial applications, more specifically in the fields of CO2 capture and storage, flow assurance, chemistry, and geoscience.

Les sédiments marins des marges continentales sont enrichis en Matière Organique Sédimentaire (MOS) qui peut être transformée en méthane par l'activité microbienne. Les précédents résultats obtenus dans le cadre du projet de recherche PAMELA ont permis d'identifier plusieurs points d’émissions de méthane biogénique sur le plateau continental du Golfe de Gascogne et le long des marges du Mozambique et de Madagascar. Afin de mieux comprendre l'impact de la nature de la Matière Organique (MO) sur ces systèmes fluides, nous avons (1) caractérisé la MO et (2) proposé une nouvelle approche de modélisation pour estimer la présence de gaz biogénique à l'échelle du bassin. Les premiers résultats concernant l'évolution du matériel organique à grande échelle dans le Canal du Mozambique, ont montré des hétérogénéités en termes de qualité et de quantité de MO entre les marges du Mozambique et de Madagascar. Nous avons conclu que les variations des signatures isotopiques peuvent être le résultat des conditions de transport et de préservation différentes entre les deux sites. Une nouvelle approche de modélisation a été appliquée au système biogénique localisé sur le rebord du plateau aquitain (Golfe de Gascogne). Les résultats ont conduit à un scénario de référence pour la production de méthane microbien dans le Bassin Aquitain offshore qui est cohérent avec les quantités de méthane émis au fond de la mer. Le gaz biogénique est généré actuellement dans les sédiments du Plio-Pléistocène, avec une quantité moyenne de gaz émis estimée entre 0,87 et 1,48 Tcf / My
Marine sediments in continental margins are known to be enriched in Sedimentary Organic Matter (SOM) which can yield methane by microbial activity. Previous results collected in the framework of the PAMELA research project allowed to identify several seepages of microbial methane offshore Aquitaine (Bay of Biscay) and along the Mozambique and Madagascar continental margins. In order to better understand the impact of the Organic Matter (OM) on such fluid systems, we (1) characterized the OM, and (2) proposed a new modelling approach to predict methane cycle at the basin scale from its generation to migration and release. The OM in the Mozambique Channel shows heterogeneities at large scale in quality and quantity between the Mozambique and the Madagascar margins. We concluded that isotopic signature variations can be the result of different transport and preservation conditions between the two sites. A new modelling approach was applied to the Bay of Biscay biogenic fluid system. It consists of a basin modelling workflow of microbial gas generation and migration process at the basin scale and accounts for OM biodegradation processes and the main biogenic gas sink. The results allowed us to propose a reference scenario for microbial gas production in offshore Aquitaine that is compared with measured data from in situ bubbling sites and acoustic water column signatures. The biogenic system appears to be sourced by biogenic gas system found in the Plio-Pleistocene sediments that is still active, with a mean flow rate estimated between 0.87 and 1.48 Tcf/My