Lithologic color‐coded sections by AVO crossplots

Verm, Richard; Hiltemmn, Fred J.

doi:10.1190/1.1822706

Cited by 8 publications

(4 citation statements)

References 1 publication

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“…Figure 7 displays the two-term inversion for Line 1 with the stack of the prestack migration overlaid as a wiggle trace. This display utilizes a color crossplot technique (Verm et al, 1995) to combine the information from For each time sample, the value of along with its corresponding value determines which color to plot.…”

Section: Presentation -Resultsmentioning

confidence: 99%

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Two‐term inversion from AVO to detect combined effect of porosity and gas in a cretaceous sand reservoir

DiSiena

Parsons²,

Hilterman

1995

SEG Technical Program Expanded Abstracts 1995

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This case study demonstrates predictions of lithology and porosity variations for a high acoustic impedance gas sand. The approach combines three techniques to estimate and interpret an acoustic impedance and Poisson ratio term by: 1. generating with AVO analysis a Normal Incidence (NI) and Poisson Reflectivity (PR) from 2. applying a recursive inversion method to independently generate estimates of acoustic impedance from NI and Poisson ratio from PR; and 3. utilizing a crossplot method to simultaneously display and as a color-coded section portraying variations in lithology, porosity and pore fluid. This approach overcomes limitations in stack seismic inversion to discriminate porosity from lithology. It also extends application of AVO to sands with exceeding shaleThe targeted channel sands lie beneath a Cretaceous shalechalk section (-14 000 feet depth). These channel sands interfinger with debris-flow facies to reach a combined thickness of 160 ft, with reservoir net pay of 69 ft. Maximum porosity is 22% with pay reservoir quality to 9%. The clean channel facies provide excellent reservoir quality, while intergranular detrital clay in the debris-flow facies reduces reservoir quality. The inversion discriminates these facies. Near the most productive wells, shows a significant drop from the background. Also, the crossplot display reveals that these sands occur within a canyon-like feature. With this definition of geometry and seismic facies, we have the potential to predict well performance in areas where interfingered sands are below seismic resolution.

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Section: Presentation -Resultsmentioning

confidence: 99%

“…We use a reflection coefficient (RC) parameterization (Verm, et al, 1995) which relates offset response to and Ao:…”

Section: Production -Data Analysismentioning

confidence: 99%

Two‐term inversion from AVO to detect combined effect of porosity and gas in a cretaceous sand reservoir

DiSiena

Parsons²,

Hilterman

1995

SEG Technical Program Expanded Abstracts 1995

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“…Hydrocarbon anomalies are usually aligned away from this trend. Verm and Hilterman (1994) reported that the different classes of AVO anomalies (Rutherford and Williams, 1989;Castagna and Swan, 1997) will be mapped in various locations on the cross-plots of intercept versus gradient (Cambois, 1998). Reflectors of different impedances and polarities will align in different zones of an intercept/gradient cross plot (Russell, 2003).…”

Section: Avo Cross Plotmentioning

confidence: 99%

Integrated AVO inversion and seismic attributes for tracing hydrocarbon accumulation in Kafr El-Sheikh Formation, South Batra field, Nile Delta, Egypt: A case study

Gobashy

DAHROUG

ZAKARIA³

et al. 2022

Contrib. Geophys. Geod.

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Utilizing advanced seismic techniques for delineating hydrocarbon accumulations in HST (High Stand System Tract) turbidite channel of Kafr El-Sheikh (KS) formation (Pliocene Age) located in the western part of South Batra field (SBF), Nile Delta – Egypt is investigated. 3D seismic data and four well logs helped in studying the properties of the channel. Three wells encountered the central part of the channel and showed thicker reservoir thickness than the fourth well, which encountered the levee. The channel is characterized by high porosity (25–30%) and relatively low water saturation (27–50%). The structural map showed that the channel is dipping towards the NE–SW. AVO analysis, scaled Poisson's ratio, post-stack seismic inversion, and seismic attributes confirmed the presence of Class III gas sand. Variance attribute helped in imaging the channel and faults. Maps generated from spectral decomposition showed that the dominant frequency is around 15 hertz. Results of integrating different techniques were consistent and successfully helped in determining the geometry of the channel, discriminating between different lithologies and fluids, in addition to delineating the sweet spots and recommended locations for drilling.

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“…We must simplify the equations for analyzing AVO characteristics with different rock physics properties, especially for detecting hydrocarbon from pre-stack seismic data. There are many ways of simplifying Zoeppritz P-P reflection coefficient equation (Aki and Richards, 1980;Shuey, 1985;Smith and Gidlow, 1987;Verm and Hilterman, 1994;Wang, 1999). All of these simplified equations provide good AVO modeling results for different reservoir models.…”

Section: Introductionmentioning

confidence: 97%

Reservoir prediction using pre-stack inverted elastic parameters

et al. 2009

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This is a case study of the application of pre-stack inverted elastic parameters to tight-sand reservoir prediction. With the development of oil and gas exploration, prestack data and inversion results are increasingly used for production objectives. The prestack seismic property studies include not only amplitude verse offset (AVO) but also the characteristics of other elastic property changes. In this paper, we analyze the elastic property parameters characteristics of gas-and wet-sands using data from four gas-sand core types. We found that some special elastic property parameters or combinations can be used to identify gas sands from water saturated sand. Thus, we can do reservoir interpretation and description using different elastic property data from the pre-stack seismic inversion processing. The prestack inversion method is based on the simplified Aki-Richard linear equation. The initial model can be generated from well log data and seismic and geologic interpreted horizons in the study area. The input seismic data is angle gathers generated from the common reflection gathers used in pre-stack time or depth migration. The inversion results are elastic property parameters or their combinations. We use a field data example to examine which elastic property parameters or combinations of parameters can most easily discriminate gas sands from background geology and which are most sensitive to pore-fluid content. Comparing the inversion results to well data, we found that it is useful to predict gas reservoirs using λ, λρ, λ/μ, and K/μ properties, which indicate the gas characteristics in the study reservoir.

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Lithologic color‐coded sections by AVO crossplots

Cited by 8 publications

References 1 publication

Two‐term inversion from AVO to detect combined effect of porosity and gas in a cretaceous sand reservoir

Two‐term inversion from AVO to detect combined effect of porosity and gas in a cretaceous sand reservoir

Integrated AVO inversion and seismic attributes for tracing hydrocarbon accumulation in Kafr El-Sheikh Formation, South Batra field, Nile Delta, Egypt: A case study

Reservoir prediction using pre-stack inverted elastic parameters

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