Geological implications of a large pressure difference across a small fault in the Viking Graben

Childs, Conrad; Manzocchi, Tom; Nell, P.A.R.; Walsh, John J.; Strand, Julian; Heath, A. E.; Lygren, T.H.

doi:10.1016/s0928-8937(02)80015-7

Cited by 16 publications

(21 citation statements)

References 11 publications

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“…The Shale Gouge Ratio (SGR) method is the most widely used permeability predictor and has been applied in a number of published studies (Manzocchi et al 1999;Childs et al 2002;Rivenaes & Dart 2002: Sperrevik et al 2002. It is based on permeability constraints indicating a negative correlation between the phyllosilicate fraction within a fault rock and its permeability (Fig.…”

Section: Shale Gouge Ratio Permeability Predictormentioning

confidence: 99%

“…9b. The precise nature of this relationship varies between studies (Childs et al 2002: Sperrevik et al 2002, a feature generally attributed to differences in factors such as the burial depth at the time of faulting and the maximum burial depth. Nevertheless the general perception is that SGR:permeability transformations should follow a negative correlation, perhaps even an approximately linear relationship on a plot of SGR against log-permeability.…”

Section: Shale Gouge Ratio Permeability Predictormentioning

confidence: 99%

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Definition of a fault permeability predictor from outcrop studies of a faulted turbidite sequence, Taranaki, New Zealand

Childs

Walsh

Manzocchi

et al. 2007

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Post-depositional normal faults within the turbidite sequence of the Late Miocene Mount Messenger Formation of the Taranaki Basin, New Zealand are characterized by granulation and cataclasis of sands and by the smearing of clay beds. Clay smears maintain continuity for high ratios of fault throw to clay source bed thickness (c. 8), but are highly variable in thickness, and gaps occur at any point between the clay source bed cut-offs at higher ratios. Although cataclastic fault rock permeabilities may be appreciably lower (c. two orders of magnitude) than host rock sandstone permeabilities, the occurrence of continuous clay smears, combined with low clay permeabilities (10s to 100s nD) means that the primary control on fault rock permeability is clay smear continuity. A new permeability predictor, the Probabilistic Shale Smear Factor (PSSF), is developed which incorporates the main characteristics of clay smearing from the Taranaki Basin. The PSSF method calculates fault permeabilities from a simple model of multiple clay smears within fault zones, predicting a more heterogeneous and realistic fault rock structure than other approaches (e.g. Shale Gouge Ratio, SGR). Nevertheless, its averaging effects at higher ratios of fault throw to bed thickness provide a rationale for the application of other fault rock mixing models, e.g. SGR, at appropriate scales.

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Section: Shale Gouge Ratio Permeability Predictormentioning

confidence: 99%

Section: Shale Gouge Ratio Permeability Predictormentioning

confidence: 99%

Definition of a fault permeability predictor from outcrop studies of a faulted turbidite sequence, Taranaki, New Zealand

Childs

Walsh

Manzocchi

et al. 2007

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“…Knai & Knipe 1998;Ottesen Ellesevet et al 1998;Manzocchi et al 1999;Childs et al 2002, Hollund et al 2002Rivenaes & Dart 2002;Yielding 2002;Jolley et al 2007;Myers et al 2007). These methods calculate multipliers for each fault connection in the model based on local estimates of fault rock permeability and thickness.…”

Section: Introductionmentioning

confidence: 99%

Faults in conventional flow simulation models: a consideration of representational assumptions and geological uncertainties

Manzocchi

Heath

Palananthakumar

et al. 2008

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Even when geologically based methods are used to determine fault rock permeabilities and thicknesses for input into flow simulators, a wide range of simplifying assumptions regarding fault structure and content are still present. Many of these assumptions are addressed by defining quantitative and flexible methods for realistic parameterization of fault-related uncertainties, and by defining automated methods for including these effects routinely in full-field flow simulation modelling. The fault effects considered include: the two-phase properties of fault rocks; the spatial distributions of naturally variable or uncertain single-phase fault rock properties and fault throws; and the frequencies and properties of sub-resolution fault system or fault zone complexities, including sub-seismic faults, normal drag and damage zones, paired slip surfaces and fault relay zones. Innovative two-phase or geometrical upscaling approaches implemented in a reservoir simulator preprocessor provide transmissibility solutions incorporating the effect, but represented within the geometrical framework of the full-field flow simulation model. The solutions and flexible workflows are applied and discussed within the context of a sensitivity study carried out on two faulted versions of the same full-field flow simulation model. Significant influence of some of these generally neglected fault-related assumptions and uncertainties is revealed.

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“…Manzocchi et al (1999) have noted, the fault rock permeability thus obtained should be regarded as a median value having an uncertainty range of two orders of magnitude, in Fig.3, the data points in the calibration are not plenty and they come from various formations and areas hence the large scatter of the data is seen. Nonetheless, the fault rock permeability thus calculated can be used (1) for comparing various parts of a fault surface, and (2) for proxy estimation of the transmissibility of faults (defined as fault rock permeability divided by fault zone thickness) in reservoir simulation (Manzocchi et al, 1999;Childs et al, 2002). In any case, the model permeability data should be ultimately checked against permeability data derived from other methods, either directly from fault-rock cores or indirectly from well logs if they hit the fault rocks.…”

Section: Fault Rock Permeabilitymentioning

confidence: 99%

Sealing assessment of normal faults in clastic reservoirs: Modeling the petrophysical and stress attributes of faults.

Sorkhabi¹,

Iwanaga²,

Fujimoto³

et al. 2003

J. JAPANESE. ASSOC. PETROL. TECHNOL.

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Abstract:We describe procedures for estimation of the petrophysical properties of fault rocks and the stress regime in normal faults as incorporated in the PC software (FAULTAP) developed at the Technology Research Center of Japan National Oil Corporation (JNOC/TRC).A quantitative appraisal of the petrophysical properties of fault rocks provides key information for fault sealing assessment and reservoir management. Empirical evidence shows that the permeability of fault rocks appears to be approximately two orders of magnitude lower than that of the host reservoir rocks. Among the deformation processes in clastic rocks, shale smear by faulting seems to be a most efficient mechanism of permeability reduction in fault rocks. The permeability of fault rocks has an inverse relationship with the clay content incorporated from the host rock as well as with the depth of fault rock and fault displacement. The relationship between clay content and pore throat radius in fault rock forms a basis for calculation of the capillary pressure of fault rock and the hydrocarbon column height that a fault can laterally support.The integrity or the failure of fault seals is crucially dependent upon how various portions of the fault surface are subjected to stress accumulation in the recent geological time. Simple methods for calculation of in-situ stresses on normal faults are presented for evaluation of fault failure by slip tendency or dilation tendency. An integration of fault failure and shale smear parameters provides a better assessment of fault sealing or potential leakage in response to the recent stress regime or changes in the pressure regime during field production.

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Geological implications of a large pressure difference across a small fault in the Viking Graben

Cited by 16 publications

References 11 publications

Definition of a fault permeability predictor from outcrop studies of a faulted turbidite sequence, Taranaki, New Zealand

Definition of a fault permeability predictor from outcrop studies of a faulted turbidite sequence, Taranaki, New Zealand

Faults in conventional flow simulation models: a consideration of representational assumptions and geological uncertainties

Sealing assessment of normal faults in clastic reservoirs: Modeling the petrophysical and stress attributes of faults.

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