Identification of Infill and Step-Out Drilling Potential Via Acoustic Inversion, 3D Seismic Attribute Analysis, and 3D Seismic Curvature Analysis: Neuquen and San Jorge Basins, Argentina

We analyzed a 1991 3D seismic data located offshore Florida and applied seismic attribute analysis to identify geological structures. Initially, the seismic data appears to have a high signal-to-noise-ratio, being of an older vintage of quality, and appears to reveal variable amplitude subparallel horizons. Additional geophysical analysis, including seismic attribute analysis, reveals that the data has excessive denoising, and that the continuous features are actually a network of polygonal faults. The polygonal faults were identified in two tiers using variance, curvature, dip magnitude, and dip azimuth seismic attributes. Inline and crossline sections show continuous reflectors with a noisy appearance, where the polygonal faults are suppressed. In the variance time slices, the polygonal fault system forms a complex network that is not clearly imaged in the seismic amplitude data. The patterns of polygonal fault systems in this legacy dataset are compared to more recently acquired 3D seismic data from Australia and New Zealand. It is relevant to emphasize the importance of seismic attribute analysis to improve accuracy of interpretations, and also to not dismiss older seismic data that has low accurate imaging, as the variable amplitude subparallel horizons might have a geologic origin.

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Along-strike structure segmentation and cross-strike transfer faults in the Middle Devonian Marcellus Shale, Pennsylvania, Central Appalachian Basin: Implications for gas recovery efficiency and risk assessment using 3D seismic attribute analysis

10.1190/segam2013-1309.1 ◽

2013 ◽

Author(s):

Emily D. Roberts ◽

Dengliang Gao

Keyword(s):

Risk Assessment ◽

Middle Devonian ◽

Marcellus Shale ◽

Appalachian Basin ◽

Recovery Efficiency ◽

3D Seismic ◽

Seismic Attribute ◽

Gas Recovery ◽

Attribute Analysis ◽

Transfer Faults

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THE DIRKALA SOUTH OIL DISCOVERY: FOCUSSING ON COST-EFFICIENT RESERVOIR DELINEATION

The APPEA Journal ◽

10.1071/aj94004 ◽

1995 ◽

Vol 35 (1) ◽

pp. 65

Author(s):

S.I. Mackie ◽

C.M. Gumley

Keyword(s):

Production Performance ◽

Seismic Survey ◽

3D Seismic ◽

Seismic Attribute ◽

Data Set ◽

Seismic Surveys ◽

Seismic Modelling ◽

Attribute Analysis ◽

Cost Efficient ◽

The Cost

The Dirkala Field is located in the southern Murta Block of PEL's 5 and 6 in the southern Cooper and Eromanga Basins. Excellent oil production from a single reservoir sandstone in the Jurassic Birkhead Formation in Dirkala-1 had indicated a potentially larger resource than could be mapped volumetrically. The hypothesis that the resource was stratigraphically trapped led to the need to define the fluvial sand reservoir seismically and thereby prepare for future development.A small (16 km2) 3D seismic survey was acquired over the area in December 1992. The project was designed not only to evaluate the limits of the Birkhead sand but also to evaluate the cost efficiency of recording such small 3D surveys in the basin.Interpretation of the data set integrated with seismic modelling and seismic attribute analysis delineated a thin Birkhead fluvial channel sand reservoir. Geological pay mapping matched volumetric estimates from production performance data. Structural mapping showed Dirkala-1 to be optimally placed and that no further development drilling was justifiable.Seismic characteristics comparable with those of the Dirkala-1 Birkhead reservoir were noted in another area of the survey beyond field limits. This led to the proposal to drill an exploration well, Dirkala South-1, which discovered a new oil pool in the Birkhead Formation. A post-well audit of the pre-drill modelling confirmed that the seismic response could be used to determine the presence of the Birkhead channel sand reservoir.The acquisition of the Dirkala-3D seismic survey demonstrated the feasibility of conducting small 3D seismic surveys to identify subtle stratigraphically trapped Eromanga Basin accumulations at lower cost and risk than appraisal/development drilling based on 2D seismic data.

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Large-scale 3D seismic attribute analysis framework based on double-layer Flood Fill

10.1190/hpc2016-005 ◽

2016 ◽

Author(s):

Chen Maoshan ◽

Hao Yanguo ◽

Dai Lihua ◽

Li Hong ◽

Wang Fei

Keyword(s):

Double Layer ◽

Large Scale ◽

3D Seismic ◽

Analysis Framework ◽

Seismic Attribute ◽

Attribute Analysis ◽

Flood Fill

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Investigation of seismic attributes, depositional environments, and hydrocarbon sweet-spot distribution in the Serbin field, Taylor Formation, Southeast Texas

Interpretation ◽

10.1190/int-2018-0041.1 ◽

2019 ◽

Vol 7 (1) ◽

pp. T49-T66

Author(s):

Osareni C. Ogiesoba ◽

William A. Ambrose ◽

Robert G. Loucks

Keyword(s):

Acoustic Impedance ◽

Depositional Environments ◽

High Resistivity ◽

3D Seismic ◽

Seismic Attribute ◽

Seismic Amplitude ◽

Attribute Analysis ◽

Property Versus ◽

Multiattribute Analysis ◽

Sweet Spots

We have conducted seismic-attribute analysis at the Serbin field — in an area straddling Lee, Fayette, and Bastrop Counties and covering approximately [Formula: see text] (approximately [Formula: see text]) — using new, reprocessed, 3D seismic data to provide additional understanding of depositional environments and better predict the distribution of hydrocarbon sweet spots. We converted the 3D seismic volume into a log-lithology volume and integrated core data to examine the distribution of lithology and interpret depositional environments. By conducting multiattribute analysis, we predicted resistivity (deep-induction log) volume and generated a resistivity map to identify hydrocarbon sweet spots. Our results show that reservoir sandstones in the Serbin field are storm-dominated, shelf-sand deposits. Although individual sandstone beds are lenticular and discontinuous, they collectively constitute a sheet-like geometry, trending northeast to southwest. On the basis of resistivity maps and rock property versus seismic-amplitude crossplots, we differentiated reservoirs in the lower Taylor Formation into two zones: (1) a northwest, high-resistivity, high-acoustic impedance zone and (2) a southeast, low-resistivity, low-acoustic impedance zone. The results also indicated that hydrocarbon sweet spots in the Serbin field are characterized by high resistivity and high impedance. Furthermore, the log-lithology method, although fast and effective, is limited because it cannot take into account sandstone zones having low acoustic impedance.

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3D seismic attributes for a tight gas sand reservoir characterization of the eastern Sulige gas field, Ordos Basin, China

Geophysics ◽

10.1190/geo2014-0362.1 ◽

2015 ◽

Vol 80 (2) ◽

pp. B35-B43 ◽

Cited By ~ 12

Author(s):

Zhiguo Wang ◽

Jinghuai Gao ◽

Daxing Wang ◽

Qiansheng Wei

Keyword(s):

Ordos Basin ◽

Seismic Attributes ◽

Gas Production ◽

Seismic Attenuation ◽

Tight Gas ◽

3D Seismic ◽

Seismic Attribute ◽

Gas Field ◽

Attribute Analysis ◽

Phase Tuning

The Lower Permian Xiashihezi Formation of the Ordos Basin is the largest producer of tight gas sand in China. The controls on tight gas production are many and include a variety of geologic, hydrodynamic, and engineering factors from one well to another throughout the basin. In this study, we considered data from a [Formula: see text] 3D seismic volume and logs from 17 wells to investigate the geologic controls on gas production in the [Formula: see text] member of the Xiashihezi Formation, eastern Sulige gas field, Ordos Basin. Our objective was to determine the potential of applying multiple seismic attributes to identify the higher productivity areas of a tight gas sand reservoir. To achieve this, we used amplitude, complex traces, spectral decomposition, and seismic attenuation attributes derived from the 3D seismic volume to detect gas-bearing sand areas. The results of seismic attribute analysis revealed that no single attribute is correlated to higher productivity areas. The qualitative correlations between attributes and production records reflected that higher productivity areas are associated with seismically definable higher amplitude, more stable phase, tuning frequency, and stronger attenuation features in the study area. Meanwhile, three outlier wells in the seismic attribute analysis provided a reminder of the uncertainty in geologic interpretation. The gas-sand reservoir evaluation results suggested that the Pareto principle helps to enhance the interpretation needed to determine the productivity distribution of [Formula: see text] tight-gas reservoir in the study area.

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