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73rd EAGE Conference and Exhibition - Workshops 2011
- Conference date: 23 May 2011 - 27 May 2011
- Location: Vienna, Austria
- ISBN: 978-90-73834-13-2
- Published: 27 May 2011
81 - 100 of 129 results
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Surface-Based Reservoir Modelling
More LessConventional grid- or pixel-based reservoir modelling algorithms have been developed to account for uncertainty associated with sparse subsurface data and to produce geological models which can be upscaled onto regular, structured grids suitable for flow simulation. However, the use of a regular grid to model the distribution of facies types and petrophysical properties limits the spatial resolution of the geological model, so these methods can fail to capture key geological heterogeneities, particularly those at small length-scales and/or with complex geometries. The upscaling step also results in a loss of fidelity. Outside the world of reservoir modelling, other disciplines have moved away from using simple structured grids to characterize complex spatial geometries. A common approach is to use unstructured meshes to discretize space within volumes defined by surfaces. We present a surface-based approach to reservoir modelling in which any geological heterogeneity that impacts on the spatial distribution of petrophysical properties, is modelled as one or more discrete volumes bounded by surfaces.
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Testing the Multi Point Statistic Modelling Approach Using Outcrop Data
Authors Robert Kil and Andrea MoscarielloThe island of Favignana provides an exceptional three-dimensional insight of the internal architecture of a Lower Pleistocene complex bioclastic calcarenitic wedge. Field data indicate that these calcarenites consist of foramol association, originated during cool to temperate water conditions in a high-energy, storm dominated, open shelf environment. Predominant sedimentary structures vary from small-scale trough cross bedding, large foresets to large scours filled by structureless massive bioclastic material. Overall a main transport direction to the SE indicates the prograding nature of these deposits. Based on the sedimentological characteristics and reservoir properties, this sedimentary complex is believed to be a relevant analogue for several important hydrocarbon fields worldwide in North Africa, Middle East and South America such as the Perla Field in Venezuela.
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The Impact of More Determinism on a Reservoir Model
More Lesse design driven in some cases) the geologist applies a variety of statistical based techniques to derive the subsurface reservoir architecture. The stochastic model then serves as a media to which can have a tendency to convince ourselves that we have improved our understanding of the subsurface (“I used my stochastic modelling tool and integrated all my log data therefore it must be geologically valid”). In this case study from the Niger Delta, the establishment of deterministic-based geological models through the use of the outcrop analogue observation principles combined with core-based and logbased facies associations are used to supersede the more common practise of stochastic (pixel-based) geological models. The aim of this paper is to demonstrate how thinking more about our conceptual geological model and less on the application of the statistical algorithm (and their inherent workflow) with the data that we have available, there is the possibility to add orders of magnitude of determinism into the geological model making the reservoir description more realistic and predictable.
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Markov Chain / Transition Probability Approach for Geo-Cellular Modeling of Carbonate Depositional Geobodies: Proof-of-Concept Markov Random Field Simulator
Authors Brigitte Vlaswinkel, Sam Purkis and Nuno GraciasA reservoir model based on subsurface data as well as appropriate (reservoir) analogs is a critical field management tool, and therefore should accurately incorporate features affecting fluid storage, distribution and flow. However, the complexity of specifically carbonate reservoirs makes detailed direct-characterisation of their 3D heterogeneity difficult, and this problem is worsened in the subsurface where lateral constraint on facies architecture is typically poor to non-existent, while information on vertical stacking maybe rich. A tantalizing strategy to mitigate this disjoint lies in the use of Walther’s Law, which offers the possibility of using vertical transitions to elucidate lateral juxtaposition motifs (Doveton 1994; Parks et al. 2000; Elfeki & Dekking 2005; Riegl & Purkis 2009). The implication being that a reservoir model, competent at least in terms of transition statistics, could be built against information harvested down-core. Coupled with simple Markov theory, it can be deduced that under such conditions, comparable facies frequencies and transition probabilities will link vertical and lateral facies stacks. If one can be quantified, the other can be solved for. It therefore follows that 2D or even 3D Markov chain models can be developed by assuming that spatial variability in any direction can be characterised by a 1D Markov chain. Although this may seem like a tenuous theoretical leap, the assumption here is merely that Markov chains might characterise spatial variability not only in the vertical but in other stratigraphic directions such as dip or strike (Carle et al. 1998). In this paper we present a proof-of-concept Markov Random Field Simulator (MRFS) and test its 3D geo-cellular modelling capabilities against a Cretaceous carbonate outcrop dataset. The assumption Walther’s Law can be applied has been verified successfully beforehand, based on two case studies that call upon (carbonate) data from the Cretaceous, Miocene and Modern (Purkis et al., submitted).
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Seismic Monitoring of CO2 Injection into a Depleted Gas Reservoir – Otway Basin Project
Authors M. Urosevic, R. Pevzner, V. Shulakov, A. Kepic, E. Caspari and S. Sharma and B. GurevichWithin the Stage I of the Otway Basin Project, of the Australian Cooperative Research Centre for Greenhouse Gas Technologies (CO2CRC), approximately 65,000 tons of CO2/CH4 mix in the ratio of 80/20 was injected into the Waarre C formation (depleted Naylor gas reservoir) over the last two years. The CO2 was produced and transported from a nearby natural accumulation, via pipeline and injected into a sandstone reservoir. The use of depleted gas fields for CO2 storage as well as CO2-based enhanced gas recovery are of global importance. Thus, the CO2CRC Otway Basin Pilot Project provides important experience in establishing whether such scenarios can be monitored by geophysical techniques, in particular seismic time-lapse methodology. Indeed injection of CO2 into a depleted gas reservoir (within residual gas saturation window) does not present favourable conditions for the application of geophysical monitoring techniques. Numerical simulation of the CO2 injection process at Otway show that changes in elasticity of the reservoir rock will be quite small and difficult to monitor even with the most powerful time-lapse (TL) seismic methodologies. Consequently, the design and implementation of the monitoring program had to address these issues. The monitoring program had two objectives: (1) to ensure detection of possible gas leakages out of the reservoir into other formations and (2) to attempt to detect changes of seismic response due to CO2 injection into the reservoir. To increase the sensitivity of TL seismic we combined 3D VSP with 3D surface seismic. For a land seismic case, we achieved excellent repeatability with 3D time lapse surveys, which at the reservoir level produced normalised RMS difference values of about 20% for surface seismic and 10% for 3D VSP, respectively. The location of the time-lapse anomaly detected at the reservoir level is broadly consistent with CO2 flow simulations. However borehole seismic measurements showed that timelapse is very small to be reliably evaluated from repeated surface seismic measurements as the anomaly is of a similar magnitude to noise, making its unique attribution to the CO2 plume difficult. One of the important outcomes of these studies is evaluation of land time-lapse seismic capabilities. New understanding and new methodologies for assessment of 3D seismic data repeatability were developed during Otway Basin tests. This helped us understand and validate time-lapse signal form the reservoir. It also enabled us to demonstrate that quality of time-lapse land surveys can be high enough to be able to detect very small, up to five thousand tonnes, leakages which is of essential importance to any monitoring program as it provides possibility for rapid mitigation.
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Monitoring and Modelling CO2 Injection at Sleipner
Authors Rob Arts and Farid Jedari EyvaziCO2 has been injected into the Utsira Sand at Sleipner since 1996, with more than 11 million tonnes currently in the reservoir. Seismic monitoring surveys to follow the migration of the CO2 in the reservoir have been carried out in 1999, 2001, 2002, 2004, 2006 and 2008. The CO2 plume is imaged on the seismic data as a prominent multi-tier feature, comprising a number of bright sub-horizontal reflections, growing with time and interpreted as arising from up to nine discrete layers of high saturation CO2, each up to a few metres thick. Quantitative seismic interpretation of the time-lapse data has included synthetic seismic modelling to derive CO2 distributions in the reservoir (Skov et al, 2002, Arts et al., 2004). Convolution-based modelling has shown that seismic reflection amplitudes are broadly related to layer thickness via a tuning relationship. However acquisition geometry, lateral velocity changes, mode conversions and intrinsic attenuation are all likely to affect amplitudes, especially at the lower levels in the reservoir, and need to be incorporated within a rigorous quantitative analysis. Moreover, the predicted response heavilly relies on a rock physics model (Arts et al., 2004) to convert simulated saturation data to seismic impedance data. In this study we present a reservoir simulation sensitivity study based on the existing models of the Utsira Sand to mimic the spreading behavior of the CO2 as observed on the time-lapse seismic data. The transmissibility of each intra-reservoir shale layer has been estimated by matching the simulated quantity of CO2 with the seismically observed (estimated) quantity of CO2 per layer. The corresponding spreading patterns per level have been compared to the seismically observed accumulations.
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Geophysical Monitoring of Small Scale CO2-injection into a Deep Saline Aquifer - the Ketzin Pilot Site
The first European onshore CO2 storage site has been set up at Ketzin (Germany). It is operated as a small scale pilot site, with a special focus on the validation of various geophysical, geochemical and microbial monitoring technologies. The site has been developed within the EU funded project CO2SINK, coordinated by the GFZ German Research Centre for Geosciences and supported by numerous national and EU initiatives. Injection started in June 2008. Since then, between 1.000 and 2.000 tons of CO2 per month have been injected into sandstone layers of the Triassic Stuttgart Formation at a depth of 620 m to 650 m. The total amount of injected CO2 was 45.000 tons in February 2011. Injection is planned to continue until up to 100.000 tons will have been injected into the Stuttgart Formation. Currently, food grade CO2 is being injected at Ketzin, however, the technical and contractual preparations are underway to inject a limited amount of CO2 from a sequestration pilot facility.
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The IEAGHG Weyburn-Midale CO2 Monitoring and Storage Project: A Project Overview and a Rebuttal to Recent Accusations of a Leak from the Reservoir
More LessThe IEAGHG Weyburn-Midale CO2 Monitoring and Storage Project is completing its final year of research in the spring of 2011. The project, which is conducted in conjunction with a two commercial enhanced oil recovery CO2 floods in South-eastern Saskatchewan, Canada, began in 2000 with a first phase that confirmed the suitability of the Weyburn oilfield formation for the long-term storage of CO2. In 2005, the final phase of the project began, offering a comprehensive research program covering • site characterization • measurement, monitoring and verification of the injected CO2 • wellbore integrity • risk and performance management This final phase has also offered an integrated approach between this technical and non-technical research, and has included an examination of regulatory issues and public communications and outreach efforts. A comprehensive best practices manual – which will offer other jurisdictions and similar project proponents the best means of transitioning CO2-EOR operations into long-term storage – is to be published in late 2011.
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Seven Years of CO2 Injection in the Nearly Depleted Gasfield K12-B
Authors V.P. Vandeweijer, L.G.H. van der Meer and F.M.M. MuldersDespite the efforts directed at the development and large scale application of sustainable energy, the world still heavily depends on fossil fuels, and will do so for at least the next decades. The challenge our world is facing is to develop technology options that allow for continued use of fossil fuels without substantial emissions of CO2 (IEA, 2000) through cost-effective capture and storage and at the same time maintaining industrial competitiveness in global markets. Subsurface storage of CO2 in geological systems could bridge the transition period required to develop sustainable sources of energy. This option is currently being studied and applied worldwide, including demonstration projects. In 2004 a demonstration project commenced where CO2 was re-injected into the gas reservoir at K12-B. This made K12-B the first location in the world where CO2 is being injected into the same reservoir from which it was produced as part of the natural gas. The K12-B gas field is located in the Dutch sector of the North Sea. The top of the reservoir lies approximately 3800 meters below sea level, and the ambient temperature of the reservoir is over 127 ºC. The K12-B gas field has been producing natural gas from 1987 onwards and is currently operated by GDF SUEZ E&P Nederland B.V. The natural gas has a CO2 content of 13% which is relatively high. Since the start of the gas production the CO2 component has been separated from the natural gas stream on-site and. since 2004 part of the separated CO2 is re-injected into the gas field. Since then numerous tests have been performed in order to investigate various aspects of underground CO2 storage in nearly depleted gas fields mainly focussing on well integrity and the behaviour of CO2 in the well and reservoir.
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Monitoring and Quantification of Stored CO2 with Combined P-wave Velocity and Resistivity
Authors Takahiro Nakajima, Ziqiu Xue and and Toshifumi Matsuokaal., 2008, Xue et al., 2002, 2005; Xue & Ohsumi 2004a, 2004b, 2005; Onishi et al., 2006). In the most CO2 storage sites, seismic survey has been conducted to monitor the injected CO2. From the recent injection projects, seismic survey shows great results for monitoring the migration of the CO2 in the reservoirs such as Sleipner or Nagaoka site (Arts et al., 2002, 2004; Bunge et al., 2000; Davis et al., 2002; Xue et al., 2006). In Nagaoka project, studies have attempted to estimate the CO2 saturation around the observation wells by using the results of well logging and laboratory studies (Kim et al., 2009b, Nakatsuka et al., 2009, Xue et al., 2006). When estimating CO2 saturation from seismic survey, Gassmann’s theory which consisted of bulk modulus of the saturated porous rock has been often used (Gassmann, 1951). When the saturation was less than 20%, P wave velocity shows good response but when the saturation was more than 20%, P-wave velocity became less sensitive to CO2 saturation. P-velocity is not sensitive to gas saturation in high gas saturation regime (Sg>20%) for either homogenous saturation or patchy saturation with patchy size << wavelength (Xue & Lei 2006, Lei & Xue 2006). To overtake this weak point of seismic monitoring for the estimation of CO2 saturation, there is a need for estimating accurate CO2 saturation using resistivity. In this paper, laboratory experiments have been conducted to monitor combined P-wave velocity and resistivity simultaneously in porous sandstone during CO2 injection process.
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Deep Saline Aquifers and Coal Seams as Potential sites for the CO2 Geological Storage in Italy.
More LessThe complex tectonic setting, the high seismic risk of the most part of its territory, and the volcanic risk associated to a large part of it, together with the high population density reduce the possibilities for a wide scale application of CO2 geological storage in Italy.
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A Natural Analogue of a CO2 reservoir: the Latera Caldera (central Italy). Insight from Field Data to Numerical Modeling of Fluid Flow through a Fracture Network.
Authors S. Bigi, Alemanni A., Battaglia M., Lombardi S., Campana A., Borisova E. and Loizzo M.Fractured volumes of rock and fault zones in the upper crust are typically composed of complex brittle discontinuities network. Determining the architecture of the fracture network and the patterns and rates of fluid flow in these structural discontinuities is a three dimensional problem. Modeling of fractures is generally performed using two basic approaches, probabilistic and deterministic. The obtained 3D models are used for numerical simulation of fluid flow, in order to identify the primary controlling parameters of fault and fractures related fluid flow. 3D probabilistic model of fractures network are based of field data (orientation, spatial distribution and density), used as input parameters, whereas deterministic models are based on kinematics and dynamic constraints. In any case, their accuracy is rather limited, due to the high number of parameters that controls fracturing processes (lithology, pressure, stresses). In this work we reconstructed a 3D fracture network directly from field data from a site that is a natural reservoir of CO2, that has been selected as a test site within the “CO2GeoNet” EC project, and than used it to simulate a fluid flow with a numerical model.
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Benefit of InSAR satellite data displacements to validate 3D reservoir pressure computation using a one way 3D fluid flow geomechanical coupled modelling at Krechba (preliminary results)
Authors J-P. Deflandre and Baroni A. and Estublier A.To successfully deploy the Carbon Capture and Storage (CCS) concept on a site, a series of milestones has necessary to be passed. One of them is to demonstrate the reliability of short term performance assessment prediction at the CO2 geological storage site. Validation must be established on a monitoring-based verification approach. It may allow after achievement to anticipate the long term fate of the CO2 within the storage complex perimeter to finally make risk management efficient. The first step consists in modelling the CO2 migration within the saline aquifer storage and the resulting reservoir pressure field of which the evolution will help in managing major risk scenarios (unsuitable fluid migration, effective stress redistribution, fault reactivation…). In the frame of the CO2ReMoVe European project, the research work program aims at developing tools and methods to reach such an objective on testing and improving them on a series of pilot sites. At In Salah (South Algeria), BP, Statoil and Sonatrach target at re-injecting the CO2 produced on a series of gas fields into the Krechba saline reservoir aquifer. Up to 1 million tons of CO2 per year will be stored during approximately 27 years. CO2 injection is achieved using three horizontal wells drilled in the northern part of the structure and started in 2004 at well Kb-501(Ringrose et al. 2009). On this industrial-scale pilot case, IFPEN worked at testing and validating a coupled fluid flowgeomechanical modelling workflow (Deflandre et al. 2010). The proposed approach presented here aims at verifying and improving the 3D fluid flow and geomechanical modelling reliability using independent InSar satellite surface displacements for comparison with computed surface displacement ones.
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Measuring ground movement with InSAR data at In Salah
Authors A. Ferretti, A. Fumagalli, F. Novali, C. Prati, F. Rocca, A. Rucci and S. CespaKnowledge of the structure controlling the fluid/gas flow at the reservoir layer is critical in many activities, such as petroleum/gas extraction and carbon capture sequestration (CCS). To this end, timelapse geophysical observations are considered as an important instrument to better understand the fluid flow in the subsurface. In the last decade, a new remote-sensing technology called PSInSAR™ - based on the use of satellite radar data - is receiving an increasing attention, thanks to its capability to provide accurate, large-scale surface deformation measurements with millimetric precision. The utility of such data for reservoir monitoring and modeling, has been proved in the InSalah project, one of the three most famous CCS project. SAR data has been used to track the injected CO2 [1], to monitor possible fault reactivation and to estimate the effective permeability of a producing gas reservoir.
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Enterprise Information Management and Information Governance 2011
More LessThe benefits of holistic information management are clear: Complete and trustworthy information allows business leaders to make better decisions faster. The perils of fragmented information management – unnecessary cost, risk and loss of productivity – are equally clear. We'll help you assess the "state of the art" of enterprise information management (EIM) and information governance and help you start or continue your own information management journey. The concept of remote computing for E&P began in earnest with the rise of the Dot Coms. However the infrastructural requirements; bandwidth, disk space, and even user-interfaces did not help to make it an immediate success.
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Cloud Computing: Will it affect E and P?
By Augustin DizThe concept of remote computing for E&P began in earnest with the rise of the Dot Coms. However the infrastructural requirements; bandwidth, disk space, and even user-interfaces did not help to make it an immediate success. The nature of the compute services has been changing. Cloud Computing, a generic name for a host of services (from infrastructure to software hosting) is generating changes.
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Adaption and use of Standard Data/Information Management methodology
By Eldar BjørgeFor many years the E&P industry has been focusing on data management of large amount of structured data (seismic, well data, production data etc). The methods and standards have been developed within the E&P industry itself. Enables have been roles and responsibilities (ownership and stewardship), standardization, data quality of large data sets and IT technology (e.g. corporate data stores for quality assured data). Emerging trends, like Enterprise Architecture and integration of structured and unstructured data, has focused on a holistic corporate view on data management. To be able to model information on an enterprise level Statoil looked into different possibilities and decided to use the DAMA1) methodology as the basis for defining IM terminology and IM functions. The DAMA framework was used to prioritize IM functions and make best common practice documents. An Enterprise Architecture project has documented the connection between processes, information and tools for all main processes. Within Information Architecture we used the recommended best practice to establish an Enterprise Data Model for all important information objects and enterprise master data. The purpose has been to make information models on enterprise and process level, available to management, projects and service providers to be used as a communication tool between business and technical personnel and as a tool for categorizing all information vital for strategic and operational business decisions or under legal requirement These activities have initiated activities within Master Data Management activities and with focus on master Data governance.
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Managing E and P Data in Norway – The National Data Repository (NDR) Diskos. Achieving Success through Collaboration
By Eric ToogoodIn 1995 the Norwegian Petroleum Directorate (NPD) and a number of key oil companies set up a joint database for the management of digital E&P data from the Norwegian Continental Shelf (NCS), the “Diskos Database” (Knudsen,1998). This collaborative Norwegian approach to the management of E&P data by the Diskos group of companies has proved to be a big success.As oil companies in Norway have an obligation to share data when participating in production licences there was a powerful incentive to reduce the redundancy of data storage by individual companies. The database is managed on commercial terms by a trusted third party operator, selected through a competitive bid process according to Norwegian and EU procurement legislation. All data is available through secure broadband access. Data in Norway can be purchased and traded, which leads to complex challenges regarding security and the management of user access to data. It is necessary, therefore, to have a technical solution that allows for sophisticated data access controls at a very fine grained level (i.e. shot-point level for seismic data and document level for reports). The PetroBanksoftware,was developed in the early 1990’s for the Diskos group and the database still runs this technology. Initially only a few oil companies were active Diskos members, but now in its 17th year the number of oil companies and institutions using the Diskos solution has grown to well over 50.
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Rollout of a Master Data Store concept on the Example of the Acreage Data Domain
More LessThe MDS Acreage project is the first rollout of the MDS concept in OMV. This presentation will give you an overview from the requirements specification till the final roll out of the MDS Acreage project. It will highlight the lesson learned from all project phases and suggest an outlook to the further implementations. The goal of the project was the replace an existing management report for OMV’s acreage data and to integrate this essential asset information into the Master Data Store environment. The process from the initial idea to the final rollout took more than two and a half years. The complexity of handling a project of such a long timeline was also within organizational changes of the company. Stuffing was replaced or changed positions. A totally new organization appeared in OMV and in parallel in E&P. Knowledge transfer and not loosing track of the initial project idea was one of the critical success criteria’s.
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Data Ownership Model in DONG E and P
More LessFor many years many technical data users in the E&P industry have held the view that data was something the Data Management Departments should take care of, "just" ensuring that all the necessary data were in the right place, in the right format at the right time. Alternatively some users held the view that the data was theirs to store and use in the formats and places they chose. It is now generally accepted, at least in the G&G user environment, that data-quality and data-availability is a shared responsibility between the users and data management professionals. Breaking down the professional silos and realizing that the same data are needed many times in the E&P value chain has also put focus on agreed standards and quality assurance. In order to promote this shared responsibility and ensure compliance a Data Ownership Model has been introduced and agreed upon in DONG E&P. The Data Ownership Model clarifies and formalizes the "ownerships" and responsibilities for the data standards and the data management processes throughout the data life cycle and hence help to maintain the integrity and quality of DONG E&P's data assets. The presentation presents the Data Ownership Model and discusses the process through which it has been developed; agreed between management, users and data management; and implemented in the organization.
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