Practical seismic petrophysics: The effective use of log data for seismic analysis

Smith, Travis A.

doi:10.1190/1.3657071

Cited by 19 publications

(7 citation statements)

References 28 publications

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“…Using seismic data, I interpret whether the traps are structural, stratigraphic, or both by identifying the structural and stratigraphic pattern of the major formations using the isopach and isochron maps. b) Data Conditioning: Because of wellbore instability, tool anomalies, and random error, subsurface data must be corrected for any extraneous and/or erroneous values (Smith, 2011). In order to provide a robust petrophysical analysis, this study incorporates two data-conditioning techniques used to organize, examine, and in some cases, rectify raw well-log data.…”

Section: Trap Characterizationmentioning

confidence: 99%

Reservoir Characterization of the Kizler North Field, Lyon Co., Kansas, Usa

Hasan¹

2018

Geological Society of America Abstracts With Programs

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The Kizler North Field is near the western flank of the Forest City Basin in Lyon Co., Kansas, USA and produces oil from the Hunton Formation, Viola Formation and Simpson Group reservoirs. The structure strikes NW through the field that is part of a larger wrench fault system. This modern prospect analysis of the Kizler North Field, aids in understanding the reservoir properties of the Hunton Formation, Viola Formation and Simpson Group rocks, the play mechanism of the field, and provides recommendations for additional drilling locations. A detailed prospect evaluation using 2D seismic data and well log data from the Kizler North Field uses 1) Contour mapping of formations with public data from wells (~n=60), 2) Structural and stratigraphic analysis of 2D seismic data, and 3) Characterization of reservoir properties from well-log data from existing wells. Correlation of 2D seismic data with well data is used to visualize structures, to detect stratigraphic features, and to interpret seismic reflection patterns of the target horizons. The Viola Formation and Simpson Group production is located at the apex of the anticlinal structure. However, time structure, isopach and isochron maps show that the Hunton Formation is significantly thinned across the axis of the anticline owing to erosion. The thinning of Hunton Formation in the structural top is also observed in the nearby analog Kizler and John Creek fields. Five wrench faults are identified in the study area, which are present only in the pre

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Section: Trap Characterizationmentioning

confidence: 99%

Reservoir Characterization of the Kizler North Field, Lyon Co., Kansas, Usa

Hasan¹

2018

Geological Society of America Abstracts With Programs

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“…Although the analyses described here focus exclusively on labbased measurements, I include comments that are particularly relevant for the application in well-based studies of carbonate reservoirs. For workflow details, the interested reader will find (siliciclastic) examples in Kittridge et al (2008) and Smith (2011). Comments that follow reference, the two-part workflow of Kittridge et al (2008), and emphasize work elements in which challenges and aspects unique to carbonate reservoirs are likely.…”

Section: Mixed Mineralogy (No Shear Velocity)mentioning

confidence: 99%

Investigating the influence of mineralogy and pore shape on the velocity of carbonate rocks: Insights from extant global data sets

Kittridge

2015

Interpretation

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Using a variety of recent public-domain data sets comprising porosity, velocity (P-and S-waves), and, in most cases, mineralogy and petrographic data, I created an extensive global data set and evaluated the importance of mineralogy and pore type on the elastic properties behavior of carbonate core plugs. Results from this investigation clearly illuminated the potential for overinterpreting elastic properties behavior as a function of pore type(s) when mineralogy was not explicitly included in the analysis. Rock-physics analysis using a combination of heuristic and theoretical models illustrated that mineralogy exerted a significant additional variation on velocity at a given porosity. Failure to account for mineralogy exacerbated inferences about the effect of pore type(s) made using a comparison of P-wave velocity to an inappropriate empirical model (Wyllie) that did not account for pore shape(s). In this analysis, extreme variability in carbonate velocity was observed in only portions of two data sets, when mineralogy was explicitly considered and robust models that accounted for inclusion (pore) shape were used. Results from this analysis resulted in a recommended workflow, including a rock-physics template and dry-rock modulus diagnostics, for the evaluation of lab-based carbonate rockphysics data. The workflow was amenable to further integration with well-based data and other core-based petrophysical measurements (e.g., electrical properties).

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“…The Vp/Vs ratio is estimated using the slope change and intercept of the modeled seismic reflections as shown in Figure 3. For models, the shear wave velocity is estimated from the logged p-velocity, porosity and shale content (Smith 2011). The Vp is strongly reduced by gas in the sand pore space while Vs is not affected by gas in the sand pore space.…”

Section: Geophysical Interpretation Of the Gas Filled Channel Sand Oumentioning

confidence: 99%

Application of Seismic Attributes in Estimating Gas Resources in Complex Fluvial Channel Reservoirs

et al. 2013

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The purpose of this paper is to show the reserve estimation procedures used by KUFPEC on the NW Shelf of Australia production license WA-49-L, which is currently under development as part of the Chevron's Wheatstone LNG project. The gas in the WA-49-L permit was discovered in a combination of structural and stratigraphic traps of a regional fluvial channel sand complex within the Triassic Mungaroo Formation. These channel sands contain gas trapped on a large structural ridge with up-dip terminations below a regional, angular unconformity and overlain by the Cretaceous Muderong Shale. Some of the deeper channel sands are trapped against the bounding fault of the ridge. These channel sands are stacked as a result of amalgamation of numerous channels, with the individual sand thickness of up to 60 meters but typically in the 15 to 30 meters range. These channel sands are discrete with individual gas-water-contacts, and clearly visible on seismic and inversion data as low impedance, Class 3 AVO (amplitude versus offset) anomalies.The estimation of gas resources is delineated by 20 wells drilled through April 2011 on WA-49-L. Limitations of the seismic frequency content result in channel thicknesses of less than 5 meters not being visible. Seismic inversion attributes are used to estimate gas sand probability, sand thickness and porosity. Rather than using large scale net-to-gross assumptions commonly used in the industry for reserves calculations, KUFPEC used maps of individual sand bodies based on the inversion impedance amplitudes and gas sand probability (GSP) attributes to compute each sands' likely range of resources values.

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Practical seismic petrophysics: The effective use of log data for seismic analysis

Cited by 19 publications

References 28 publications

Reservoir Characterization of the Kizler North Field, Lyon Co., Kansas, Usa

Reservoir Characterization of the Kizler North Field, Lyon Co., Kansas, Usa

Investigating the influence of mineralogy and pore shape on the velocity of carbonate rocks: Insights from extant global data sets

Application of Seismic Attributes in Estimating Gas Resources in Complex Fluvial Channel Reservoirs

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