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  • 1
    Monograph available for loan
    Monograph available for loan
    London : The Geological Society
    Associated volumes
    Call number: 9/M 07.0421(347)
    In: Geological Society special publication
    Description / Table of Contents: Reservoir compartmentalization the segregation of a petroleum accumulation into a number of individual fluid/pressure compartments controls the volume of moveable oil or gas that might be connected to any given well drilled in a field, and consequently impacts booking of reserves and operational profitability. This is a general feature of modern exploration and production portfolios, and has driven major developments in geoscience, engineering and related technology. Given that compartmentalization is a consequence of many factors, an integrated subsurface approach is required to better understand and predict compartmentalization behaviour, and to minimize the risk of it occurring unexpectedly. This volume reviews our current understanding and ability to model compartmentalization. It highlights the necessity for effective specialist discipline integration, and the value of learning from operational experience in: detection and monitoring of compartmentalization; stratigraphic and mixed-mode compartmentalization; and fault-dominated compartmentalization.
    Type of Medium: Monograph available for loan
    Pages: VI, 362 S. : farb. Ill., graph. Darst.
    ISBN: 9781862393165
    Series Statement: Geological Society special publication 347
    Classification:
    Deposits
    Location: Reading room
    Branch Library: GFZ Library
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  • 2
    Description / Table of Contents: Reservoir compartmentalization - the segregation of a petroleum accumulation into a number of individual fluid/pressure compartments - controls the volume of moveable oil or gas that might be connected to any given well drilled in a field, and consequently impacts ‘booking’ of reserves and operational profitability. This is a general feature of modern exploration and production portfolios, and has driven major developments in geoscience, engineering and related technology. Given that compartmentalization is a consequence of many factors, an integrated subsurface approach is required to better understand and predict compartmentalization behaviour, and to minimize the risk of it occurring unexpectedly. This volume reviews our current understanding and ability to model compartmentalization. It highlights the necessity for effective specialist discipline integration, and the value of learning from operational experience in: detection and monitoring of compartmentalization; stratigraphic and mixed-mode compartmentalization; and fault-dominated compartmentalization.
    Pages: Online-Ressource (VI, 362 Seiten)
    ISBN: 9781863293165
    Language: English
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  • 3
    Keywords: Hydrodynamik ; Kohlenwasserstofflagerstätte ; Störung (Geologie) ; Failles (Géologie) ; Failles (géologie) ; Faults (Geology) ; Fluid dynamics ; Huiles minérales - Fluides, Mécanique des ; Hydrocarbon reservoirs ; Mineral oils - Fluid dynamics ; Pétrole - Géologie
    Description / Table of Contents: R. J. Knipe, G. Jones, and Q. J. Fisher: Faulting, fault sealing and fluid flow in hydrocarbon reservoirs: an introduction / Geological Society, London, Special Publications, 147:vii-xxi, doi:10.1144/GSL.SP.1998.147.01.01 --- Fault Array Mapping, Geometry and Evolution --- C. Townsend, I. R. Firth, R. Westerman, L. Kirkevollen, M. Hårde, and T. Andersen: Small seismic-scale fault identification and mapping / Geological Society, London, Special Publications, 147:1-25, doi:10.1144/GSL.SP.1998.147.01.02 --- Ø. Steen, E. Sverdrup, and T. H. Hanssen: Predicting the distribution of small faults in a hydrocarbon reservoir by combining outcrop, seismic and well data / Geological Society, London, Special Publications, 147:27-50, doi:10.1144/GSL.SP.1998.147.01.03 --- D. Marchal, M. Guiraud, T. Rives, and J. van den Driessche: Space and time propagation processes of normal faults / Geological Society, London, Special Publications, 147:51-70, doi:10.1144/GSL.SP.1998.147.01.04 --- Faulting Processes and Fault Seal Characterization --- J. T. Adams and C. Dart: The appearance of potential sealing faults on borehole images / Geological Society, London, Special Publications, 147:71-86, doi:10.1144/GSL.SP.1998.147.01.05 --- K. A. Foxford, J. J. Walsh, J. Watterson, I. R. Garden, S. C. Guscott, and S. D. Burley: Structure and content of the Moab Fault Zone, Utah, USA, and its implications for fault seal prediction / Geological Society, London, Special Publications, 147:87-103, doi:10.1144/GSL.SP.1998.147.01.06 --- D. C. P. Peacock, Q. J. Fisher, E. J. M. Willemse, and A. Aydin: The relationship between faults and pressure solution seams in carbonate rocks and the implications for fluid flow / Geological Society, London, Special Publications, 147:105-115, doi:10.1144/GSL.SP.1998.147.01.07 --- Q. J. Fisher and R. J. Knipe: Fault sealing processes in siliciclastic sediments / Geological Society, London, Special Publications, 147:117-134, doi:10.1144/GSL.SP.1998.147.01.08 --- B. M. Krooss, S. Schloemer, and R. Ehrlich: Experimental investigation of molecular transport and fluid flow in unfaulted and faulted pelitic rocks / Geological Society, London, Special Publications, 147:135-146, doi:10.1144/GSL.SP.1998.147.01.09 --- D. R. Faulkner and E. H. Rutter: The gas permeability of clay-bearing fault gouge at 20°C / Geological Society, London, Special Publications, 147:147-156, doi:10.1144/GSL.SP.1998.147.01.10 --- Experimental and Numerical Modelling of Deformation and Fluid Flow --- S. K. Matthäi, A. Aydin, D. D. Pollard, and S. G. Roberts: Numerical simulation of departures from radial drawdown in a faulted sandstone reservoir with joints and deformation bands / Geological Society, London, Special Publications, 147:157-191, doi:10.1144/GSL.SP.1998.147.01.11 --- P. S. D’Onfro, W. D. Rizer, J. H. Queen, E. L. Majer, J. E. Peterson, T. M. Daley, D. W. Vasco, A. Datta-Gupta, and J. C. S. Long: An integrated approach for characterizing fractured reservoirs / Geological Society, London, Special Publications, 147:193-208, doi:10.1144/GSL.SP.1998.147.01.12 --- B. Maillot, P. Cowie, and D. Lague: Simulating polyphase faulting with a tensorial 3D model of fault growth / Geological Society, London, Special Publications, 147:209-216, doi:10.1144/GSL.SP.1998.147.01.13 --- C. G. Fleming, G. D. Couples, and R. S. Haszeldine: Thermal effects of fluid flow in steep fault zones / Geological Society, London, Special Publications, 147:217-229, doi:10.1144/GSL.SP.1998.147.01.14 --- J. R. Henderson: The influence of fault compaction on fault zone evolution / Geological Society, London, Special Publications, 147:231-242, doi:10.1144/GSL.SP.1998.147.01.15 --- P. C. Leary: Relating microscale rock-fluid interaction to macroscale fluid flow structure / Geological Society, London, Special Publications, 147:243-260, doi:10.1144/GSL.SP.1998.147.01.16 --- D. Lesnic, L. Elliott, D. B. Ingham, R. J. Knipe, and B. Clennell: An inverse problem to determine the piecewise homogeneous hydraulic conductivity within rocks / Geological Society, London, Special Publications, 147:261-268, doi:10.1144/GSL.SP.1998.147.01.17 --- Structure and Seal Analysis of Hydrocarbon Fields --- T. A. Knai and R. J. Knipe: The impact of faults on fluid flow in the Heidrun Field / Geological Society, London, Special Publications, 147:269-282, doi:10.1144/GSL.SP.1998.147.01.18 --- S. Ottesen Ellevset, R. J. Knipe, T. Svava Olsen, Q. J. Fisher, and G. Jones: Fault controlled communication in the Sleipner Vest Field, Norwegian Continental Shelf; detailed, quantitative input for reservoir simulation and well planning / Geological Society, London, Special Publications, 147:283-297, doi:10.1144/GSL.SP.1998.147.01.19 --- J. B. Ericsson, H. C. McKean, and R. J. Hooper: Facies and curvature controlled 3D fracture models in a Cretaceous carbonate reservoir, Arabian Gulf / Geological Society, London, Special Publications, 147:299-312, doi:10.1144/GSL.SP.1998.147.01.20
    Pages: Online-Ressource (XXI, 319 Seiten) , Illustrationen, Diagramme, Karten
    ISBN: 1862390223
    Language: English
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  • 4
    Publication Date: 2008-01-02
    Description: Reservoir compartmentalization is one of the key issues that affects the development and production phase of gas fields. To improve prediction of the effects of compartmentalization on production, a new method has been developed to allow petroleum engineers to incorporate geologically-reasonable fault rock flow properties into upscaled dynamic reservoir simulation models. The first stage of the workflow is to estimate the permeability and capillary characteristics of fault rocks within the field. These data are then combined with estimates of fault rock thickness, derived from outcrop studies, to calculate transmissibility multipliers to take into account the impact of faults on fluid flow within the dynamic model. Our method differs from most others in that we have attempted to account for the two-phase flow properties of fault rocks in the dynamic models from producing reservoirs. Application of the model to real field examples provides far faster history matching than has been achieved previously. In addition, taking into account the multi-phase flow properties of fault rocks explains production behaviour that previous models could not. Although, the focus of this study has been on the Southern Permian Basin in the North Sea, the same approach could be applied to other areas.
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  • 5
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    In:  Geological Society Special Publication 292: 219-233.
    Publication Date: 2008-01-02
    Description: This paper describes basic rules-of-thumb' that offer an indication of common uncertainties and pitfalls, as well as the analytical methods, data requirements and work elements required to replicate the impact of faults on fluid flow in production simulation models successfully. The first, and most important, stage in this modelling process is to ensure that an accurate structural interpretation is incorporated into the simulation model. In particular, that all fault linkages and cross-fault juxtapositions are taken from the seismic interpretation into the simulation grid. Fault rocks sometimes reduce the rate of cross-fault flow in which case it is important to account for this reduction in flow within simulation models. This is best achieved if databases of fault rock properties, measured from the field of interest or nearby similar reservoirs, are up-scaled to calculate fault transmissibility multipliers. It is sometimes necessary to consider not just the single-phase permeability but also the capillary pressure and relative permeability characteristics of the fault rocks present. Finally, all the relevant static and dynamic data must be appraised critically. However, the interpretation of such data is usually non-unique and misinterpretations can create errors in the production-related fault seal analysis. Where these basic guidelines are followed, it has been our experience that the project time required to achieve a history match of production data is dramatically reduced. In addition, as the history match is more geologically reasonable, the model is often more reliable for predicting the long-term behaviour of the reservoir. This gives confidence in the model's forecast to guide development planning and day-to-day field management decisions.
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  • 6
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    In:  Geological Society Special Publication 347: 1-8.
    Publication Date: 2010-11-08
    Description: Reservoir Compartmentalization - the segregation of a petroleum accumulation into a number of individual fluid/pressure compartments - occurs when flow is prevented across ‘sealed’ boundaries in the reservoir. These boundaries are caused by a variety of geological and fluid dynamic factors, but there are two basic types: ‘static seals’ that are completely sealed and capable of withholding (trapping) petroleum columns over geological time; and ‘dynamic seals’ that are low to very low permeability flow baffles that reduce petroleum cross-flow to infinitesimally slow rates. The latter allow fluids and pressures to equilibrate across a boundary over geological time-scales, but act as seals over production time-scales, because they prevent cross-flow at normal production rates - such that fluid contacts, saturations and pressures progressively segregate into ‘dynamic’ compartments. Thus, reservoir compartmentalization impacts the volume of moveable (produceable) oil or gas that might be connected to any given well drilled in a field, which restricts the volume of reserves that can be ‘booked’ for that field. Booking of reserves is tightly regulated by government authorities because it is a key measure used by stock analysts and investors to value an oil company. This places reservoir compartmentalization studies, and the predictive science and technology applied to them, at the heart of company valuation. Unexpected compartmentalization can also seriously impact the profitability of a field: with more data acquisition, more study, more wells, more time being required to produce less oil and gas than was originally anticipated. In extreme cases, this might even lead to early...
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  • 7
    Publication Date: 2007-10-08
    Description: In this study, Upper Cretaceous Shetland Group mudstone cuttings from a range of depths in the Northern North Sea, have been studied using X-ray diffraction, mercury porosimetry and electron microscopy. Millimetre to micrometre mudstone textures have been quantified using image analysis of backscattered electron microscope images. Relatively shallow samples (1615 m) have isotropic mudstone fabric (no alignment of clay minerals), are dominated by smectite and have porosity values of approximately 35%. In contrast, more deeply buried samples (3300 m) have developed an anisotropic fabric (distinct alignment of clay minerals), are dominated by illite and have porosity values of approximately 22%. The change in mineralogy is due to smectite replacement by illite, which occurs simultaneously with porosity-loss and fabric development during progressive burial. Image analysis of differentially buried mudstones has proved to be a rapid, flexible and quantitative method for characterizing mudstone textures. The coincidence of mineralogical evolution with textural development and compaction implies that the transformation of smectite to illite occurs by dissolution and precipitation and that chemically facilitated compaction may contribute to porosity loss.
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  • 8
    Publication Date: 2007-11-05
    Description: To investigate the interaction between the rheology of arenaceous sedimentary rocks (sand and sandstone) and stress conditions during burial we have coupled published results from deformation experiments with a simple quartz cementation model. The model provides valuable insights into controls on sandstone deformation consistent with observations from nature. A transitional zone exists in subsiding sedimentary basins, here referred to as the ductile-to-brittle transition (DBT), above which faults in normally pressured arenites will tend to form fluid flow barriers, and below which they will tend to form conduits. The DBT depth in sandstone is dependent upon geothermal gradient, burial rate and grain size. Low geothermal gradients, rapid sedimentation rates and coarse grain sizes favour a deep DBT and vice versa. Fine-grained arenites may only deform in a brittle manner for most natural burial rates and geothermal gradients, explaining why they do not usually contain thick deformation band zones. Coarser-grained arenites may deform in a brittleductile or ductile manner, which is why they often contain thick deformation band zones and occasionally experience pervasive porosity collapse. Sandstones within high geothermal gradient areas may deform to produce fluid flow conduits at shallow depths when porosities in the sequence as a whole are high; this possibly favours fault-related mineralization.
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  • 9
    Publication Date: 2008-01-02
    Description: Improving the accuracy of subsurface imaging is commonly the main incentive for including the effects of anisotropy in seismic processing. However, the anisotropy itself holds valuable information about rock properties and, as such, can be viewed as a seismic attribute. Here we summarize results from an integrated project that explored the potential to use observations of seismic anisotropy to interpret lithological and fluid properties (the SAIL project). Our approach links detailed petrofabric analyses of reservoir rocks, laboratory based measurements of ultrasonic velocities in core samples, and reservoir-scale seismic observations. We present results for the Clair field, a CarboniferousDevonian reservoir offshore Scotland, west of the Shetland Islands. The reservoir rocks are sandstones that are variable in composition and exhibit anisotropy on three length-scales: the crystal, grain and fracture scale. We have developed a methodology for assessing crystal-preferred-orientation (CPO) using a combination of electron back-scattered diffraction (EBSD), X-ray texture goniometry (XRTG) and image analysis. Modal proportions of individual minerals are measured using quantitative X-ray diffraction (QXRD). These measurements are used to calculate the intrinsic anisotropy due to CPO via Voigt-Reuss-Hill averaging of individual crystal elasticities and their orientations. The intrinsic anisotropy of the rock is controlled by the phyllosilicate content and to a lesser degree the orientation of quartz and feldspar; the latter can serve as a palaeoflow indicator. Our results show remarkable consistency in CPO throughout the reservoir and allow us to construct a mathematical model of reservoir anisotropy. A comparison of CPO-predicted velocities and those derived from laboratory measurements of ultrasonic signals allows the estimation of additional elastic compliance terms due to grain-boundary interactions. The results show that the CPO estimates are good proxies for the intrinsic anisotropy of the clean sandstones. The more micaceous rocks exhibit enhanced anisotropy due to interactions between the phyllosilicate grains. We then compare the lab-scale predictions with reservoir-scale measurements of seismic anisotropy, based on amplitude variation with offset and azimuth (AVOA) analysis and non-hyperbolic moveout. Our mathematical model provides a foundation for interpreting the reservoir-scale seismic data and improving the geological modelling of complex reservoirs. The observed increases in AVOA signal with depth can only be explained with an increase in fracturing beneath the major unit boundaries, rather than a change in intrinsic CPO properties. In general, the style and magnitude of anisotropy in the Clair field appears to be indicative of reservoir quality.
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  • 10
    Publication Date: 2013-10-09
    Description: Hydraulic overpressure can induce fractures and increase permeability in a range of geological settings, including volcanological, glacial and petroleum reservoirs. Here we consider an example of induced hydraulic fracture stimulation in a tight-gas sandstone. Successful exploitation of tight-gas reservoirs requires fracture networks, either naturally occurring, or generated through hydraulic stimulation. The study of seismic anisotropy provides a means to infer properties of fracture networks, such as the dominant orientation of fracture sets and fracture compliances. Shear wave splitting from microseismic data acquired during hydraulic fracture stimulation allows us to not only estimate anisotropy and fracture properties, but also to monitor their evolution through time. Here, we analyse shear wave splitting using microseismic events recorded during a multistage hydraulic fracture stimulation in a tight-gas sandstone reservoir. A substantial rotation in the dominant fast polarization direction () is observed between the events of stage 1 and those from later stages. Although large changes in have often been linked to stress-induced changes in crack orientation, here we argue that it can better be explained by a smaller fracture rotation coupled with an increase in the ratio of normal to tangential compliance ( Z N / Z T ) from 0.3 to 0.6. Z N / Z T is sensitive to elements of the internal architecture of the fracture, as well as fracture connectivity and permeability. Thus, monitoring Z N / Z T with shear wave splitting can potentially allow us to remotely detect changes in permeability caused by hydraulic stimulation in a range of geological settings.
    Print ISSN: 0956-540X
    Electronic ISSN: 1365-246X
    Topics: Geosciences
    Published by Oxford University Press on behalf of The Deutsche Geophysikalische Gesellschaft (DGG) and the Royal Astronomical Society (RAS).
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