The Importance of Seismic Attributes in Complex Area, Case Study from Vodianivske Field, Dnieper-Donets Basin, Ukraine

2021 ◽  
Author(s):  
Ivan Khabanets ◽  
Benjamin Medvedev ◽  
Carlo D'Aguanno ◽  
Diego Scapin ◽  
Marco Mantova
Keyword(s):  
High Resolution ◽  
Frequency Tuning ◽  
Seismic Attributes ◽  
Hydrocarbon Exploration ◽  
Donets Basin ◽  
Small Scale ◽  
Lower Permian ◽  
Seismic Attribute ◽  
Block Boundary ◽  
Time Migration

Abstract The Dnieper-Donets Basin (DDB) is the principal producer of hydrocarbons in Ukraine and reserves are found in lower Permian and in Visean-Serpukhovian from Lower Carboniferous. The Vodianivske field is located halfway between Poltava and Kharkiv in east Ukraine with proven reserves at depth of 5-6km. Previous studies based on legacy seismic data show thickness changes of the upper Visean towards the main structure and dim small-scale structures on the block boundary. A recent 3D data reprocessing using 5D interpolation and advanced prestack time migration provides a broad frequency content image and imparts detailed high-resolution geological events. While traditional exploration is focused on gas traps in the Visean and below, current study aims to scan for potential traps in the Serpukhovian and above. In order to reveal thin section features, multiple seismic attributes were tested, and spectral decomposition was found to be a powerful tool that delineated thin sand bodies in river valleys and allowed interpretation of high-resolution small-scale faults and pinch-outs not seen before. Frequency tuning analysis on mapped horizons associated with upper Serpukhovian supported the presence of a large deltaic structure revealing SE-NW thin ∼1km wide sand body and developed set of crossing meanders. Similar approach was applied on legacy data expanding to the east and while seismic quality was limited, it was possible to identify a narrow ∼25km length meander and highlight a fault set. Upon seismic attribute study we were able to identify and map thin units associated with sands that can be considered as future targets in hydrocarbon exploration in the area.

Applying principal component analysis to seismic attributes for interpretation of evaporite facies: Lower Triassic Jialingjiang Formation, Sichuan Basin, China

2017 ◽  
Vol 5 (4) ◽  
pp. T461-T475 ◽  
Author(s):  
Suyun Hu ◽  
Wenzhi Zhao ◽  
Zhaohui Xu ◽  
Hongliu Zeng ◽  
Qilong Fu ◽  
...  
Keyword(s):  
Principal Component Analysis ◽  
Gamma Ray ◽  
Principal Component ◽  
Lower Triassic ◽  
Component Analysis ◽  
Seismic Attributes ◽  
Hydrocarbon Exploration ◽  
Seismic Survey ◽  
Seismic Attribute ◽  
Siliciclastic Rocks

In China and elsewhere, it is important to predict different lithologies and lithofacies for hydrocarbon exploration in a mixed evaporite-carbonate-siliciclastic system. The lower section of the second member of the Jialingjiang Formation (T1j2L) is mainly composed of anhydrite, dolostone, limestone, and siliciclastic rocks, providing a rare opportunity to reconstruct detailed facies in a [Formula: see text] 3D seismic survey with 31 wells. Wireline logs (sonic, density, and gamma ray) calibrated by core analysis are essential in distinguishing anhydrite, siliciclastics, and carbonates. Although different lithologies are characterized by different acoustic impedance (AI), with certain overlapping, it is still difficult to predict lithology by any single seismic attribute because of the limited seismic resolution in a thinly interbedded formation of multiple lithologies. In our study, principal component analysis (PCA) was applied to extract lithologic information from selected seismic attributes; the first two principal components were used to predict the content of anhydrite, siliciclastics, and carbonates. Content maps of anhydrite, siliciclastics, and carbonates — created by mixing the represented color — were used to reconstruct lithofacies of the T1j2L submember. It is quite difficult, even with the PCA approach, to uniquely resolve the three lithologies due to the overlapped AI and the limited resolution of the seismic data. However, the workflow that we evaluated dramatically improved the prediction accuracy of lithology and lithofacies. Facies transition during the deposition of the T1j2L submember in the study area was inferred from a paleo-uplift in the southwest to a restricted lagoon and then to an open marine setting in the northeast.

Enhanced ant tracking: Using a multispectral seismic attribute workflow to improve 3D fault detection

2021 ◽  
Vol 40 (7) ◽  
pp. 502-512
Author(s):  
Mateo Acuña-Uribe ◽  
María Camila Pico-Forero ◽  
Paul Goyes-Peñafiel ◽  
Darwin Mateus
Keyword(s):  
Random Noise ◽  
Seismic Attributes ◽  
Hydrocarbon Exploration ◽  
Fault Identification ◽  
Complex Task ◽  
Frequency Filtering ◽  
Seismic Attribute ◽  
Interpretation Process ◽  
Seismic Volumes ◽  
Fault Interpretation

Fault interpretation is a complex task that requires time and effort on behalf of the interpreter. Moreover, it plays a key role during subsurface structural characterization either for hydrocarbon exploration and development or well planning and placement. Seismic attributes are tools that help interpreters identify subsurface characteristics that cannot be observed clearly. Unfortunately, indiscriminate and random seismic attribute use affects the fault interpretation process. We have developed a multispectral seismic attribute workflow composed of dip-azimuth extraction, structural filtering, frequency filtering, detection of amplitude discontinuities, enhancement of amplitude discontinuities, and automatic fault extraction. The result is an enhanced ant-tracking volume in which faults are improved compared to common fault-enhanced workflows that incorporate the ant-tracking algorithm. To prove the effectiveness of the enhanced ant-tracking volume, we have applied this methodology in three seismic volumes with different random noise content and seismic characteristics. The detected and extracted faults are continuous, clean, and accurate. The proposed fault identification workflow reduces the effort and time spent in fault interpretation as a result of the integration and appropriate use of various types of seismic attributes, spectral decomposition, and swarm intelligence.

Application of 3D seismic attribute analysis to structure interpretation and hydrocarbon exploration southwest Pennsylvania, Central Appalachian Basin: A case study

2016 ◽  
Vol 4 (3) ◽  
pp. T291-T302 ◽  
Author(s):  
Thomas Donahoe ◽  
Dengliang Gao
Keyword(s):  
Shear Zones ◽  
Appalachian Basin ◽  
Structural Features ◽  
Hydrocarbon Exploration ◽  
Small Scale ◽  
3D Seismic ◽  
Seismic Attribute ◽  
Data Set ◽  
Fracturing Process ◽  
Southwest Pennsylvania

In the Central Appalachian Basin, southwest Pennsylvania, recently collected high-quality 3D seismic data provide critical information vital to the delineation of basin structures and depositional facies. It is therefore important for the development and verification of ideas associated with structural architecture and growth history of the basin. Traditional wiggle trace imagery has a low dominant frequency and signal-to-noise ratio. The conventional seismic attributes extracted from this data set, such as amplitude, frequency, and phase, are not effective at defining structural details and relations between faults and folds. To overcome these limitations, we have applied waveform regression, jointly with variance, and ant tracking to increase the resolution of structural features, leading to enhanced observations and interpretations. Forethrust to backthrust patterns and small-scale, intrainterval shear zones or detachment faults were observed within the Devonian intervals in which the Marcellus Shale has been developed. From the trend of discontinuities, the primary stress orientation during the Devonian was defined at approximately 105°–120° azimuth, which may affect drilling orientations in the hydraulic fracturing process of the Marcellus gas shale reservoir. Initial observations of gas production data hint at a correlation between structural quiescence and increased productivity in this study area. This effort demonstrates the importance of innovative 3D seismic-attribute techniques and analysis to understanding the relationship of subsurface structural features that are fundamental to the success of future exploration for and production of oil and gas.

Delineation of Carbonate Buildups Using Advanced Seismic Attributes, NW Sirte Basin, Libya

2021 ◽  
pp. 159-168
Author(s):  
Muneer Abdalla
Keyword(s):  
Seismic Data ◽  
Carbonate Platform ◽  
Median Filter ◽  
Random Noise ◽  
Seismic Attributes ◽  
Small Scale ◽  
Seismic Attribute ◽  
Attribute Analysis ◽  
Data Conditioning ◽  
Sirte Basin

The Paleocene reservoir formations of the Northwest Sirte Basin in North-central, Libya contains chaotic and mound-shaped seismic geometries that may have an impact on the performance of the reservoirs. It is crucial to characterize and interpret these complex geometries for future field development. Therefore, this study was utilized numerous seismic attributes to characterize and enhance the interpretation of the chaotic and mounded geometries. Data conditioning represented by spectral whitening and median filter was first applied to enhance the quality of the seismic data and remove random noise resulted from data acquisition and processing. It provided high-resolution seismic data and better-displayed edges and sedimentological features. Variance, root mean square (RMS), curvature, and envelope attributes were computed from the post-stack 3D seismic data to better visualize and interpret the chaotic and mound-like seismic geometries. Based on the seismic attribute analysis, the chaotic facies were interpreted as barrier reefs forming the margins of an isolated carbonate platform, whereas the small-scale mound-shaped facies was interpreted as patch reefs developed on the platform interior. Data conditioning methods and seismic attribute analysis that were applied to the 3-D seismic data have effectively improved the detection and interpretation of the chaotic and mounded facies in the study area. Keywords: Carbonate buildup, data conditioning, seismic attributes, Sirte Basin, Libya

Categorizing and correlating diffractivity attributes with seismic-reflection attributes using autoencoder networks

Geophysics ◽  
2020 ◽  
Vol 85 (4) ◽  
pp. O59-O70
Author(s):  
Sergius Dell ◽  
Jan Walda ◽  
Andreas Hoelker ◽  
Dirk Gajewski
Keyword(s):  
Spectral Decomposition ◽  
Seismic Reflection ◽  
Seismic Attributes ◽  
Learning Approach ◽  
Fracture Density ◽  
Seismic Attribute ◽  
Edge Diffraction ◽  
Time Migration ◽  
Fault Interpretation ◽  
Decomposition Class

Seismic attributes play a crucial role in fault interpretation and mapping fracture density. Conventionally, seismic attributes derived from migrated reflections are used for this purpose. The attributes derived from the other counterparts of the recorded wavefield are often ignored and excluded from the categorization. We have performed categorization of the attributes derived from the diffracted part of the wavefield and combine them into a new seismic attribute class, which we call diffractivity attributes. The extraction of diffractivity attributes is based on the 3D Kirchhoff time migration operator that includes a dynamic muting. We distinguish three major classes in the diffractivity attributes, which describe geometric and amplitude properties of the seismic diffractions. We assign point and edge diffraction focusing as well as the azimuth to the geometric class. The amplitudes of the isolated seismic diffractions are used to extract the instantaneous attributes based on the complex-trace approach. The instantaneous amplitudes, phase, frequency, and sweetness build up the instantaneous attribute class. We perform a spectral decomposition of the isolated diffractions into the isofrequencies using the wavelet approach. The isofrequencies compose the spectral-decomposition class. We also link the new diffractivity class to the conventional seismic reflection attributes. We use a deep learning approach based on convolutional neural networks for classifying and correlating the diffractivity attributes.

Fracture detection using multi seismic attributes ant-tracking in the Rag-e-Sefid oilfield, SW Iran

2021 ◽  
Author(s):  
Zahra Tajmir Riahi ◽  
Khalil Sarkarinejad ◽  
Ali Faghih ◽  
Bahman Soleimany ◽  
Gholam Reza Payrovian
Keyword(s):  
Seismic Data ◽  
Large Scale ◽  
Seismic Attributes ◽  
Structural Features ◽  
Hydrocarbon Exploration ◽  
Small Scale ◽  
Northwestern Part ◽  
3D Seismic ◽  
Petroleum Reservoir ◽  
Well Data

<p><strong>Abstract</strong></p><p>The detailed characterization of faults and fractures can give valuable information about the fluid flow through petroleum reservoir and directly affect the hydrocarbon exploration and production programs. In this study, large- and small-scale fractures in the Asmari horizon of the Rag-e-Sefid oilfield were characterized using seismic attribute and well data analyses. Different spatial filters including finite median hybrid (SO-FMH), dip-steered median, dip-steered diffusion, and fault enhancement filters were used on 3D seismic data to reduce noise, enhance the seismic data quality, and create a 3D seismic steering cube. In the next step, seismic attributes such as coherency, similarity, variance, spectral decomposition, dip, and curvature were applied to identify structural features. In order to check the validity of these structural features, results from seismic attributes calibrated by the interpreted fractures from image logs in the Rag-e-Safid oilfield. Then, the ant-tracking algorithm applied on the selected seismic attributes to highlight faults and fractures. These attributes combined using neural network method to create multi-seismic attributes, view different fault- or fold-sensitive seismic attributes in a single image, and facilitate the large-scale fractures extraction process. Finally, automatic fault and fracture extraction technique used to reduce human intervention, improve accuracy and efficiency for the large-scale fracture interpretation and extraction from edge volumes in the Asmari horizon of the Rag-e-Sefid oilfield. In addition to, small- scale fractures were characterized by the obtained information from the image logs interpretation for sixteen wells. All the detected fractures from seismic and well data have been divided into eight fracture sets based on their orientation and using the statistical analysis. The obtained results show that fractures characteristics and their origin are different in the northwestern and southeastern parts of the Rag-e-Sefid oilfield. The NW Rag-e-Sefid and Nourooz Hendijan Izeh Faults reactivation during Zagros orogeny led to create the dextral shear zone and P, R, R′, T, Y- fracture sets in the northwestern part of the Rag-e-Safid oilfield. Also, activity of the SE-Rag-e-Sefid thrust fault during Zagros orogeny caused to form fault-related fractures sets in the southeastern part of the Rag-e-Sefid field. In addition to, axial, cross axial, oblique fracture sets in the Asmari horizon of the Rag-e-Sefid oilfield were created by folding phase during Zagros orogeny. The obtained results were used to fracture modeling in the Asmari horizon of the Rag-e-Sefid oilfield.</p>

scholarly journals Geomorphological Geometries and High-Resolution Seismic Sequence Stratigraphy of Malay Basin’s Fluvial Succession

2021 ◽  
Vol 11 (11) ◽  
pp. 5156
Author(s):  
Abd Al-Salam Al-Masgari ◽  
Mohamed Elsaadany ◽  
Numair A. Siddiqui ◽  
Abdul Halim Abdul Latiff ◽  
Azli Abu Bakar ◽  
...  
Keyword(s):  
High Resolution ◽  
Sequence Stratigraphy ◽  
Three Dimensional ◽  
Seismic Attributes ◽  
Seismic Facies ◽  
Seismic Sequence ◽  
3D Seismic ◽  
Seismic Sequences ◽  
Seismic Sequence Stratigraphy ◽  
Point Bars

This study identified the Pleistocene depositional succession of the group (A) (marine, estuarine, and fluvial depositional systems) of the Melor and Inas fields in the central Malay Basin from the seafloor to approximately −507 ms (522 m). During the last few years, hydrocarbon exploration in Malay Basin has moved to focus on stratigraphic traps, specifically those that existed with channel sands. These traps motivate carrying out this research to image and locate these kinds of traps. It can be difficult to determine if closely spaced-out channels and channel belts exist within several seismic sequences in map-view with proper seismic sequence geomorphic elements and stratigraphic surfaces seismic cross lines, or probably reinforce the auto-cyclic aggregational stacking of the avulsing rivers precisely. This analysis overcomes this challenge by combining well-log with three-dimensional (3D) seismic data to resolve the deposition stratigraphic discontinuities’ considerable resolution. Three-dimensional (3D) seismic volume and high-resolution two-dimensional (2D) seismic sections with several wells were utilized. A high-resolution seismic sequence stratigraphy framework of three main seismic sequences (3rd order), four Parasequences sets (4th order), and seven Parasequences (5th order) have been established. The time slice images at consecutive two-way times display single meandering channels ranging in width from 170 to 900 m. Moreover, other geomorphological elements have been perfectly imaged, elements such as interfluves, incised valleys, chute cutoff, point bars, and extinction surfaces, providing proof of rapid growth and transformation of deposits. The high-resolution 2D sections with Cosine of Phase seismic attributes have facilitated identifying the reflection terminations against the stratigraphic amplitude. Several continuous and discontinuous channels, fluvial point bars, and marine sediments through the sequence stratigraphic framework have been addressed. The whole series reveals that almost all fluvial systems lay in the valleys at each depositional sequence’s bottom bars. The degradational stacking patterns are characterized by the fluvial channels with no evidence of fluvial aggradation. Moreover, the aggradation stage is restricted to marine sedimentation incursions. The 3D description of these deposits permits distinguishing seismic facies of the abandoned mud channel and the sand point bar deposits. The continuous meandering channel, which is filled by muddy deposits, may function as horizontal muddy barriers or baffles that might isolate the reservoir body into separate storage containers. The 3rd, 4th, and 5th orders of the seismic sequences were established for the studied succession. The essential geomorphological elements have been imaged utilizing several seismic attributes.

scholarly journals Circum-nuclear molecular disks: Role in AGN fueling and feedback

2019 ◽  
Vol 15 (S359) ◽  
pp. 312-317
Author(s):  
Francoise Combes
Keyword(s):  
Black Hole ◽  
Angular Momentum ◽  
High Resolution ◽  
Large Scale ◽  
Active Galaxy ◽  
Small Scale ◽  
Massive Black Hole ◽  
Molecular Outflows ◽  
Molecular Outflow

AbstractGas fueling AGN (Active Galaxy Nuclei) is now traceable at high-resolution with ALMA (Atacama Large Millimeter Array) and NOEMA (NOrthern Extended Millimeter Array). Dynamical mechanisms are essential to exchange angular momentum and drive the gas to the super-massive black hole. While at 100pc scale, the gas is sometimes stalled in nuclear rings, recent observations reaching 10pc scale (50mas), may bring smoking gun evidence of fueling, within a randomly oriented nuclear gas disk. AGN feedback is also observed, in the form of narrow and collimated molecular outflows, which point towards the radio mode, or entrainment by a radio jet. Precession has been observed in a molecular outflow, indicating the precession of the radio jet. One of the best candidates for precession is the Bardeen-Petterson effect at small scale, which exerts a torque on the accreting material, and produces an extended disk warp. The misalignment between the inner and large-scale disk, enhances the coupling of the AGN feedback, since the jet sweeps a large part of the molecular disk.

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