Empirical estimation of fault rock properties

Sperrevik, S.; Gillespie, Paul; Fisher, Q.J.; Halvorsen, Trond; Knipe, R. J.

doi:10.1016/s0928-8937(02)80010-8

Cited by 130 publications

(192 citation statements)

References 28 publications

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“…Thereby, the SGR analysis is applied to get the percentage of shale volume information between sand-sand juxtaposition. The SGR presents the shale percentage inside sand-sand juxtaposition, which is calculated from shale volume in a reservoir layer and throw of the fault movement [18][19][20]. This means that the percentage of SGR strongly controls the character of faults in terms of sealing or leaking.…”

Section: The Application Of Fsa For Reservoir Compartment Assessmentmentioning

confidence: 99%

Reservoir Compartment Assessment: A Case Study of Bangko and Bekasap Formation, Central Sumatra Basin Indonesia

Haris¹,

Anindya

Indra³

et al. 2018

GEOMATE

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ABSTRACT:The reservoir compartment assessment for a case study of the Agur field, Central Sumatra Basin has been successfully carried out by using fault seal analysis (FSA). The objective of this paper is to asses subsurface fault properties in term of the fault sealing that was defining the hydrocarbon reservoir compartment. In this work, the FSA was performed by integrating juxtaposition, shale gouge ratio (SGR) and transmissibility analysis over fault plane that was identified within reservoir layers on the Bangko and Bekasap formation. The juxtaposition seal is intended to assess how the reservoir layer is juxtaposed across the fault plane over either reservoir or non-reservoir layer. The SGR analysis is applied to estimate the shale content in the fault plane, which is caused by the fault movement of sequence stratigraphy. The last analysis of transmissibility is carried out to calculate the capacity of a reservoir to drain the hydrocarbon through a fault plane. Faults architecture (throw, heave, and orientation) and the reservoir layer target were identified based on 3D seismic and well log data interpretation. The FSA is applied to nine faults that formed nine reservoir compartments within three reservoir layers, which are obtained from 3D seismic and well log interpretation. The fault characteristics were classified and the fault seal distribution map was produced to identify the reservoir connectivity among the faults. The FSA results show that nine identified compartments in the first reservoir layer are clustered into five compartments. In addition, the FSA clustered nine identified compartments in the second reservoir layer into four compartments. In contrast, nine compartments in the third reservoir layer were connected each other that are clustered into one compartment. These results are useful not only for evaluating future hydrocarbon traps but also for future field development.

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Section: The Application Of Fsa For Reservoir Compartment Assessmentmentioning

confidence: 99%

Reservoir Compartment Assessment: A Case Study of Bangko and Bekasap Formation, Central Sumatra Basin Indonesia

Haris¹,

Anindya

Indra³

et al. 2018

GEOMATE

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“…Where displacement is less than reservoir F o r P e e r R e v i e w thickness, fluid can potentially flow across the fault into the adjacent fault block. Hydrocarbon column heights which can be supported by the fault are therefore dependent on both the fault geometry and the fault rock petrophysical properties (Yielding et al, 1997(Yielding et al, , 2010Fisher and Knipe, 1998;Sperrevik et al, 2002). Conversely, where displacement is greater than reservoir thickness a juxtaposition seal can be formed between the adjacent fault blocks where units of contrasting permeability are juxtaposed and no shallower hanging wall units are in proximity.…”

Section: Tilted Fault Blocks and Volumetricsmentioning

confidence: 99%

“…The column height which can be supported is controlled by the structural spill point and the top seal integrity. In the situation where the juxtaposed lithology is not impermeable, then the column height which can be supported depends on the sealing capacity of the fault rocks (Yielding et al, 1997;Fisher and Knipe, 1998;Sperrevik et al, 2002;Bretan et al, 2003;Yielding, 2012). This is a function of the fault rock capillary entry pressure and the buoyancy of the hydrocarbon column (Schowalter, 1979;Watts 1987;Fisher et al, 2001;Brown, 2003).…”

Section: Fault Rock Supported Column Heightmentioning

confidence: 99%

“…Column height estimation is often conducted by relating threshold pressure, and hence column height, to fault rock clay content, either through direct sample measurements (Sperrevik et al, 2002) or using the Shale Gouge Ratio (SGR) algorithm as a proxy (Bretan et al, 2003). Neither approach is ideal given the inherent heterogeneity of geological systems, with a less deterministic, semi-probabilistic approach being preferred (Childs et al, 2007;Yielding, 2012).…”

Section: Fault Rock Supported Column Heightmentioning

confidence: 99%

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Understanding regional-scale structural uncertainty: The onshore Gulf of Corinth rift as a hydrocarbon exploration analogue

et al. 2015

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A major challenge when exploring for hydrocarbons in frontier areas is a lack of data coverage. Data may be restricted to regional scale 2D seismic lines, from which assumptions of the 3D geometric configuration are drawn. Understanding the limitations and uncertainties when extrapolating 2D data into 3D space is crucial when assessing the requirements for acquiring additional data such as 3D seismic or exploration wells, and of assigning geologically reasonable uncertainty ranges.The Onshore Gulf of Corinth Rift provides an excellent analogue for rift-scale structural uncertainty in the context of hydrocarbon exploration. Here we use seismic forward modelling to explore this area of uncertainty. Synthetic seismic sections have been generated across the rift based upon fault geometries mapped in the field. Comparison of these sections with the mapped geometries allows quantification of uncertainties encountered when extrapolating 2D data into three dimensions. We demonstrate through examples how potential column heights may be both severely over-and under-estimation due to trap integrity, spill point depth and fault seal ambiguities directly related to fault geometric uncertainty. In addition, fault geometries and linkages also control the location of hanging wall syn-rift reservoirs. Hence, gross reservoir volumes and sediment facies distributions are also significantly influenced by how fault geometries are extrapolated along-strike from 2D to 3D.

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“…It is well known that clay content plays a significant role in reducing permeability in fault rocks developed within siliciclastic rocks (e.g. , 2001Manzocchi et al 1999;Sperrevik et al 2002). Consequently algorithms have been developed which attempt to calculate the distribution of average clay content (and therefore the general permeability distribution) within fault zones-from the reservoir properties, clay content and shale bed distributions within the adjacent stratigraphy-at a similar scale to that of a typical simulation model fault (cf.…”

Section: Fault Zone Propertiesmentioning

confidence: 99%

Structurally complex reservoirs: an introduction

Jolley

Barr

Walsh

et al. 2007

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Structurally complex reservoirs form a distinct class of reservoir, in which fault arrays and fracture networks, in particular, exert an over-riding control on petroleum trapping and production behaviour. With modern exploration and production portfolios commonly held in geologically complex settings, there is an increasing technical challenge to find new prospects and to extract remaining hydrocarbons from these more structurally complex reservoirs. Improved analytical and modelling techniques will enhance our ability to locate connected hydrocarbon volumes and unswept sections of reservoir, and thus help optimize field development, production rates and ultimate recovery. This volume reviews our current understanding and ability to model the complex distribution and behaviour of fault and fracture networks, highlighting their fluid compartmentalizing effects and storage-transmissivity characteristics, and outlining approaches for predicting the dynamic fluid flow and geomechanical behaviour of structurally complex reservoirs. This introductory paper provides an overview of the research status on structurally complex reservoirs and aims to create a context for the collection of papers presented in this volume and, in doing so, an entry point for the reader into the subject. We have focused on the recent progress and outstanding issues in the areas of: (i) structural complexity and fault geometry; (ii) the detection and prediction of faults and fractures; (iii) the compartmentalizing effects of fault systems and complex siliciclastic reservoirs; and (iv) the critical controls that affect fractured reservoirs.Structurally complex reservoirs form a distinct class of reservoir in which fault arrays and fracture networks, in particular, exert an over-riding control on petroleum trapping and production behaviour

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Empirical estimation of fault rock properties

Cited by 130 publications

References 28 publications

Reservoir Compartment Assessment: A Case Study of Bangko and Bekasap Formation, Central Sumatra Basin Indonesia

Reservoir Compartment Assessment: A Case Study of Bangko and Bekasap Formation, Central Sumatra Basin Indonesia

Understanding regional-scale structural uncertainty: The onshore Gulf of Corinth rift as a hydrocarbon exploration analogue

Structurally complex reservoirs: an introduction

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