Schlumberger (Norway)

In this paper, we review most major filtering approaches to texture feature extraction and perform a comparative study. Filtering approaches included are Laws masks (1980), ring/wedge filters, dyadic Gabor filter banks, wavelet transforms, wavelet packets and wavelet frames, quadrature mirror filters, discrete cosine transform, eigenfilters, optimized Gabor filters, linear predictors, and optimized finite impulse response filters. The features are computed as the local energy of the filter responses. The effect of the filtering is highlighted, keeping the local energy function and the classification algorithm identical for most approaches. For reference, comparisons with two classical nonfiltering approaches, co-occurrence (statistical) and autoregressive (model based) features, are given. We present a ranking of the tested approaches based on extensive experiments.

Abstract A simple petrophysical model proposed by Waxman and Smits (WS)1 in 1968 and Waxman and Thomas (WT)2 in 1972 accounts for the results of an extensive experimental study on the effects of clays on the resistivity of shaly sands. This model has been well accepted by the industry despite a few inconsistencies with experimental results. It is proposed that these inconsistencies resulted from the unaccounted presence of salt-free water at the clay/water interface. Electrochemistry indicates that this water should exist, but is there enough to influence the results? Both a theoretical study and reinterpretation of Waxman-Smits-Thomas data show that there is. The corresponding new model starts from the Waxman and Smits concept of supplementing the water conductivity with a conductivity from the clay counterions. The crucial step, however, is equating each of these conductivity terms to a particular type of water, each occupying a representative volume of the total porosity. This approach has been named the "dual-water" (DW) model because of these two water types—the conductivity and volume fraction of each being predicted by the model. The DW model has been tested on most of the core data reported in Refs. 1 and 2. The DW concept is also supported by log data3 and has been successfully applied to the interpretation of thousands of wells. However, the scope of this paper remains limited to the theoretical and experimental bases of the DW model.

Abstract We present a multidimensional multiple-attenuation method that does not require any subsurface information for either surface or internal multiples. To derive these algorithms, we start with a scattering theory description of seismic data. We then introduce and develop several new theoretical concepts concerning the fundamental nature of and the relationship between forward and inverse scattering. These include (1) the idea that the inversion process can be viewed as a series of steps, each with a specific task; (2) the realization that the inverse-scattering series provides an opportunity for separating out subseries with specific and useful tasks; (3) the recognition that these task-specific subseries can have different (and more favorable) data requirements, convergence, and stability conditions than does the original complete inverse series; and, most importantly, (4) the development of the first method for physically interpreting the contribution that individual terms (and pieces of terms) in the inverse series make toward these tasks in the inversion process, which realizes the selection of task-specific subseries. To date, two task-specific subseries have been identified: a series for eliminating free-surface multiples and a series for attenuating internal multiples. These series result in distinct algorithms for free-surface and internal multiples, and neither requires a model of the subsurface reflectors that generate the multiples. The method attenuates multiples while preserving primaries at all offsets; hence, these methods are equally well suited for subsequent poststack structural mapping or prestack amplitude analysis. The method has demonstrated its usefulness and added value for free-surface multiples when (1) the overburden has significant lateral variation, (2) reflectors are curved or dipping, (3) events are interfering, (4) multiples are difficult to identify, and (5) the geology is complex. The internal-multiple algorithm has been tested with good results on band-limited synthetic data; field data tests are planned. This procedure provides an approach for attenuating a significant class of heretofore inaccessible and troublesome multiples. There has been a recent rejuvenation of interest in multiple attenuation technology resulting from current exploration challenges, e.g., in deep water with a variable water bottom or in subsalt plays. These cases are representative of circumstances where 1-D assumptions are often violated and reliable detailed subsurface information is not available typically. The inverse scattering multiple attenuation methods are specifically designed to address these challenging problems. To date it is the only multidimensional multiple attenuation method that does not require 1-D assumptions, moveout differences, or ocean-bottom or other subsurface velocity or structural information for either free-surface or internal multiples. These algorithms require knowledge of the source signature and near-source traces. We describe several current approaches, e.g., energy minimization and trace extrapolation, for satisfying these prerequisites in a stable and reliable manner.

Fundamentals of Seismic Wave Propagation, published in 2004, presents a comprehensive introduction to the propagation of high-frequency body-waves in elastodynamics. The theory of seismic wave propagation in acoustic, elastic and anisotropic media is developed to allow seismic waves to be modelled in complex, realistic three-dimensional Earth models. This book provides a consistent and thorough development of modelling methods widely used in elastic wave propagation ranging from the whole Earth, through regional and crustal seismology, exploration seismics to borehole seismics, sonics and ultrasonics. Particular emphasis is placed on developing a consistent notation and approach throughout, which highlights similarities and allows more complicated methods and extensions to be developed without difficulty. This book is intended as a text for graduate courses in theoretical seismology, and as a reference for all academic and industrial seismologists using numerical modelling methods. Exercises and suggestions for further reading are included in each chapter.

Fundamentals of Seismic Wave Propagation, published in 2004, presents a comprehensive introduction to the propagation of high-frequency body-waves in elastodynamics. The theory of seismic wave propagation in acoustic, elastic and anisotropic media is developed to allow seismic waves to be modelled in complex, realistic three-dimensional Earth models. This book provides a consistent and thorough development of modelling methods widely used in elastic wave propagation ranging from the whole Earth, through regional and crustal seismology, exploration seismics to borehole seismics, sonics and ultrasonics. Particular emphasis is placed on developing a consistent notation and approach throughout, which highlights similarities and allows more complicated methods and extensions to be developed without difficulty. This book is intended as a text for graduate courses in theoretical seismology, and as a reference for all academic and industrial seismologists using numerical modelling methods. Exercises and suggestions for further reading are included in each chapter.

Summary Drift-flux modeling techniques are commonly used to represent two- and three-phase flow in pipes and wellbores. Unlike mechanistic models, drift-flux models are continuous, differentiable, and relatively fast to compute, so they are well suited for use in wellbore flow models within reservoir simulators. Drift-flux models require a number of empirical parameters. Most of the parameters used in current simulators were determined from experiments in small-diameter (2 in. or less) pipes. These parameters may not be directly applicable to flow in wellbores or surface facilities, however, because the flow mechanisms in small pipes can differ qualitatively from those in large pipes. In order to evaluate and extend current drift-flux models, an extensive experimental program was initiated. The experiments entailed measurement of water/gas, oil/ water, and oil/water/gas flows in a 15-cm-diameter, 11-m-long plexiglass pipe at eight deviations ranging from vertical to slightly downward. In this paper, these experimental data are used to determine drift-flux parameters for steady-state two-phase flows of water/gas and oil/water in large-diameter pipes at inclinations ranging from vertical to near-horizontal. The parameters are determined using an optimization technique that minimizes the difference between experimental and model predictions for phase in-situ volume fraction. It is shown that the optimized parameters provide considerably better agreement with the experimental data than do the existing default parameters.

Summary This paper presents an evaluation of two fundamentally different stress models: an elastic model, which is based on linear transverse isotropic elasticity, and a failure model, which is based on the concept that rocks are in an equilibrium state of shear failure. The models arc evaluated by using physical parameters measured on core, pore pressure, and in-situ stress data from the Gas Research Institute (GRI) Staged Field Experiments (SFE's) in east Texas. It is shown that the elastic and failure models provide satisfactory predictions for most of the lithologies encountered. However, the failure model is more accurate for predicting stress in soft shales. An example of stress predictions based on log-derived elasticity parameters that gives stress estimations comparable to core-based predictions is also shown.

Astronomy, like any experimental subject, needs statistical methods to interpret data reliably. This practical handbook presents the most relevant statistical and probabilistic machinery for use in observational astronomy. Classical parametric and non-parametric methods are covered, but there is a strong emphasis on Bayesian solutions and the importance of probability in experimental inference. Chapters cover basic probability, correlation analysis, hypothesis testing, Bayesian modelling, time series analysis, luminosity functions, and clustering. The book avoids the technical language of statistics in favour of demonstrating astronomical relevance and applicability. It contains many worked examples, and problems that make use of databases which are available on the Web. It is suitable for self-study at advanced undergraduate or graduate level, as a reference for professional astronomers, and as a textbook basis for courses in statistical methods in astronomy.

Summary This paper presents a physical model for predicting flow pattern, void fraction, and pressure drop during multiphase flow in vertical wells. The hydrodynamic conditions giving rise to various flow patterns are first analyzed. The method for predicting void fraction and pressure drop is then developed. In the development of the equations for pressure gradient, the contribution of the static head, frictional loss, and kinetic energy loss are examined. Laboratory data from various sources show excellent agreement with the model.

Summary A deviated well with an undersection trajectory (i.e., a trajectory lying below the conventional tangent section and constantly building to target) can exhibit lower drag and torque than a conventional well geometry in certain circumstances. The influence of well geometry on drag and torque is discussed, making use of the results of the theoretical model. Although an undersection well may have a reduced overall drag, the side forces in the drill collars will be increased. This can lead to a greater danger of sticking in the bottomhole assembly (BHA). Furthermore, because of the enhanced side forces near the bit, an undersection well may also exhibit greater torque. The relative merits of constant-build and catenary trajectories are discussed.

Abstract We prove that under certain conditions the inversion problem for the generalized Radon transform reduces to solving a Fredholm integral equation and we obtain the asymptotic expansion of the symbol of the integral operator in this equation. We consider applications of the generalized Radon transform to partial differential equations with variable coefficients and provide a solution to the inversion problem for the attenuated and exponential Radon transforms.

Abstract A Self-Diverting-Acid (SDA) using a Visco-Elastic Surfactant (VES) has been developed. The viscosity of the solution does not develop until the acid reacts with carbonate in the formation. The increases in Ca2+ ions and pH due to the HCl-carbonate reaction cause in situ gelling of the acid. The high viscosity temporarily blocks the wormholes formed in the rock matrix, allowing the acid to cover the un-acidized area. The viscosity of the gelled acid can be completely reduced by post flush of solvent or by the hydrocarbon in the formation during flow back. Unlike the polymer based gelled acid systems, the new material does not leave any residue once it has broken. Multi-Core flood testing incorporating a post acidizing Computed Tomography (CT) scans showed that the VES based Self-Diverting-Acid successfully diverted acid from high permeability section into lower permeability sections. The rock face remained clean without any trace of residue. Rheology measurements showed the consistency of the viscosity development by the gelled acid upon reacting with carbonates.

Summary Rock-formation permeability is one important flow parameter associated with subsurface production and injection. Its importance is reflected by the numberof available techniques (well-log evaluation, core measurements, and well testing) typically used to estimate it. The literature is full of comparisons and correlations of permeability from these sources. Too often these comparisons and correlations are used to make important conclusions without proper regard to the interrelationships among them. Permeability estimates by individual techniques within the various permeability sources can vary with the state of rock (in-situ environment), fluid saturation distribution, flow direction, and the scale of the medium under investigation. This paper reviewsthe commercially available permeability-estimation techniques and discusses theimportant factors that illustrate their interrelationships. Knowledge ofappropriate interrelationships among the various techniques allows meaningful permeability comparisons and correlations. Usefulness of the interrelationships is demonstrated with field data. Also, the interrelationship concepts presentedare a cornerstone for reservoir flow characterization. Introduction Of all the formation parameters that petroleum engineers use, permeability is one of the most important. In the oil and gas industry it is used todetermine whether a well should be completed and brought on line. Permeabilityis also essential in overall reservoir management and development (e.g., forchoosing the optimal drainage points and production rate, optimizing completionand perforation design, and devising EOR patterns and injection conditions). Oil and gas companies use both accurate and approximate permeability values. These values frequently are compared and correlated without much attention tohow each value was determined. Such comparisons and correlations are then usedto make important conclusions about formation flow potential and for variousaspects of reservoir management and development. But establishing a correlation between unstressed core plug permeability and drillstem-testing (DST) permeability and then using the correlation with other unstressed core plugpermeabilities to evaluate the flow potential of other zones, for example, maybe futile unless the scale factor, measurement environment, and physics are adequately considered. The scale factor considers the relative size of thevolumes being investigated and the nature of heterogeneity, and the measurementenvironment and physics consider the state of the rock environment, fluid saturation distribution, flow direction, and sensitivity of the measured or inferred variables that constitute permeability calculations. To address the appropriate correlations among techniques, we first define the various permeabilities that are measured by the permeabilities that are measured by thevarious techniques. Permeability Definitions Permeability Definitions The classic definition of permeability, as described by Darcy, is the intrinsic characteristic of amaterial that determines how easily a fluid can pass through it. In the petroleum industry, the darcy is the standard unit of measure for permeability. It represents 1 cm3 of fluid with a viscosity of 1 cp flowing through a 1-cm2cross-sectional area of rock in 1 second under a pressure gradient of 1 atm per1 cm of length in the direction of flow. This intrinsic rock property is called absolute permeability when the rock is 100% saturated permeability when therock is 100% saturated with one fluid phase. Permeability is also measured inreference to a fluid phase when the rock is saturated with a multiple-fluidphase. Such a permeability is the effective permeability of the rock to the particular flowing fluid. (The ratio of effective to absolute permeability isthe relative permeability.) These definitions are simple and straight forward when the measurement is performed in the laboratory. when downhole rockpermeability is measured, however, complications arise because of lack ofknowledge about the downhole environment, the volume, and the measurement method. Almost every discipline within the oil industry has its own definition of permeability. This inconsistency creates a significant problem whenpermeability is to be used problem when permeability is to be used to defme theproduction performance of a particular formation, reservoir, or well.particular formation, reservoir, or well. A core analyst's version ofpermeability may be an accurate representation of the 1-in.-diameter,1-in.-long core sample; however, the measured value may have no significantbearing on the production characteristic of the formation represented by the core sample. The core measures absolute permeability, but formation flow isgoverned by relative permeability. Also, core permeabilities permeability. Also, core permeabilities are influenced by the microscopic nature of themeasurement and the environment (absence of in-situ pressure, temperature, and saturation conditions). At times, a combination of these influences may resultin a permeability that corresponds to the well flow performance, but this ismore a coincidence than a planned result. Similar consequences are observedwhen petrophysicists evaluate permeability with log-measured values. Most logmethods, except the repeat-formation-tester (RFTSM) method, measure absolute permeability. Even though the parameters used to infer permeability from logsare measured at in-situ conditions, the complexity of rock structures and inadequate parameterization make the log less than parameterization make thelog less than derived permeability transforms nonuniversal. JPT P. 578

Summary A geochemical logging tool (GLTSM) string, measuring natural, activation, and prompt neutron-capture gamma rays, produces logs of the most abundant and a few trace inorganic element concentrations. Direct measurements of Al concentrations are provided. A geochemically based closure model is used to derive Si, Ca, Fe, S, Gd, and Ti concentrations. The only significant spectroscopically undetermined element, Mg, is inferred by comparing measured with derived photoelectric factor. Analysis algorithms, demonstrations of accuracy and precision, and applications of geochemically derived formation properties are discussed.

An expression for computing fracture pressure gradient in Gulf Coast sands as a function of overburden pressure, pore pressure, porosity, Poisson's ratio, and well depth is developed using Biot's stress/strain relationships. Then, using field data, an empirical relationship is established between Poisson's ratio and the shaliness of the sand as derived from well logs. Introduction While drilling a well, it is often necessary to increase mud weight to contain high pore pressures. A potential hazard arises because an increase in mud weight may cause one of the exposed formations to fracture, resulting in loss of circulation. Lost circulation is a dangerous and troublesome problem, often taking several days to correct, and in some cases leading to the loss of a well. The usual preventive measure is to set a protective casing string. When and where to set casing are important decisions governing the cost and safety of drilling a well, and these decisions clearly require an accurate knowledge of pore pressure gradients and fracture pressure gradients. Considerable work has been done in the last few years in the area of determining fracture pressure gradients. The numerous methods proposed vary greatly and point up the fact that the oil industry still needs an accurate and reliable answer to the problem. Following the work done by Hubbert and Willis in 1957 and Matthews and Kelly in 1967, Eaton in 1969 published a technique to predict fracture pressure gradients. In each of the above methods, the formation properties that influence the fracture pressure either are ignored or are assumed to be monotonic functions of depth. Matthews and Kelly used an empirical "matrix stress coefficient," which is a monotonic function of depth, to represent formation properties. Eaton introduced Poisson's ratio as an important elastic constant and made use of Poisson's ratio as an important elastic constant and made use of the concept of a variable overburden. However, he again resorted to general trends to describe Poisson's ratio as a function of depth. In their treatment of formation properties, both methods are essentially the same. For preparing a drilling plan, these rather general approaches for representing the influence of formation properties are valuable to the drilling engineer. Once the general trends have been established in a given field, these methods can be used to estimate fracture pressures before the well is drilled. Thus maximum mud weights can be reasonably forecast; and with some knowledge of the pore pressure trend in the field, casing points can be roughly estimated. However, it will be shown that the fracture pressure gradient can vary significantly at a given depth in the same geological field. Some means of identifying weak and strong sands, while the well is being drilled and logged, would therefore be valuable. For example, an exposed weak sand just below a casing string severely restricts mud weights during attempts to drill as far as possible into an overpressured transition shale. Conversely, there is no point in setting a casing string deeper to protect a strong sand. point in setting a casing string deeper to protect a strong sand. JPT P. 1259

Abstract The primary goal of a hydraulic fracturing treatment is to create a highly conductive flow path to the wellbore that economically increases well production. In moderate and high permeability wells the lack of adequate fracture conductivity is a limiting factor in the production potential of the well, whereas in tight gas reservoirs the limiting factor is often the effective fracture half-length. Even in the last case, adequate fracture conductivity is important to allow efficient recovery of the fracturing fluid. Traditionally, efforts to enhance conductivity have been directed to improve the ability to flow through a porous proppant pack. The industry has extended significant efforts towards the goal of increasing proppant pack permeability through the development of less damaging carrier fluids, higher strength man-made proppants, more efficient fracturing fluid breakers and so on. As an industry however, we continue to struggle with the fact that well testing frequently indicates disappointingly shorter or less conductive fractures than designed. Multiple studies indicate that proppant-pack retained permeability is often a small fraction of the maximum expected value. This manuscript describes a novel hydraulic fracturing technique that enables a step-change approach towards increasing fracture conductivity. The technique is based on the creation of a network of open channels inside the fracture. Modeling and experimental work indicates that the new technique can deliver conductivities in excess of ten-times those obtained from conventional fracture treatments. Extensive lab-, yard- and field- scale experiments combined with theoretical work allowed creating the framework that describes the physical processes occurring during the application of this new technique. By providing significantly higher fracture conductivity, this new fracturing approach delivers a number of consequential benefits: better fracture cleanup; lower pressure loss within the fracture; longer effective fracture half-lengths, all of which will contribute to improved short- and long-term production. A 15-well field study, selected from over fifty treatments performed up to date with this technique, is presented to show posttreatment results with significant gains in well production and expected ultimate recovery with respect to offset wells treated with conventional fracturing methods.

PreviousNext No AccessSEG Technical Program Expanded Abstracts 2000Three‐dimensional texture attributes for seismic data analysisAuthors: Trygve RandenErik MonsenClaude SignerArve AbrahamsenJan Ove HansenToril SæterJürgen SchlafTrygve RandenLars Sønneland, Schlumberger Stavanger Research, Erik MonsenLars Sønneland, Schlumberger Stavanger Research, Claude SignerLars Sønneland, Schlumberger Stavanger Research, Arve AbrahamsenLars Sønneland, Schlumberger Stavanger Research, Jan Ove HansenLars Sønneland, Schlumberger Stavanger Research, Toril SæterLars Sønneland, Schlumberger Stavanger Research, and Jürgen SchlafLars Sønneland, Schlumberger Stavanger Researchhttps://doi.org/10.1190/1.1816155 SectionsAboutPDF/ePub ToolsAdd to favoritesDownload CitationsTrack CitationsPermissions ShareFacebookTwitterLinked InReddit Permalink: https://doi.org/10.1190/1.1816155FiguresReferencesRelatedDetailsCited byUsing a dynamic representation of sedimentary structural features in prestack inversion: A case study in a tight sandstone in the Sichuan BasinTing Chen, Yaojun Wang, Hanpeng Cai, Bangli Zou, Gang Yu, Yalin Li, and Guangmin Hu13 December 2023 | GEOPHYSICS, Vol. 89, No. 1Automated seismic semantic segmentation using attention U-NetHaifa AlSalmi and Ahmed H. Elsheikh11 December 2023 | GEOPHYSICS, Vol. 89, No. 13D reflection seismic imaging of natural gas/fluid escape features in the deep-water Orange Basin of South Africa25 May 2023 | Marine Geophysical Research, Vol. 44, No. 2Visualizing subtle structural and stratigraphic features on 3D seismic-reflection data: A case study from offshore LibyaNabil Khalifa and Stefan Back28 April 2023 | Interpretation, Vol. 11, No. 2Evidencing subtle faults in deep seismic reflection profiles: Data pre-conditioning and seismic attribute analysis of the legacy CROP-04 profile31 March 2023 | Frontiers in Earth Science, Vol. 11Visualizing subtle structural and stratigraphic features on 3D seismic-reflection data: a case study from offshore LibyaNabil Khalifa and Stefan Back27 February 2023 | Interpretation, Vol. 0, No. jaFault identification based on the kernel principal component analysis-genetic particle swarm optimization-support vector machine algorithm for seismic attributes in the Sihe Coal Mine, Qinshui Basin, ChinaKe Ren, Guangui Zou, Suping Peng, Hen-Geul Yeh, Bowen Deng, and Yin Ji28 December 2022 | Interpretation, Vol. 11, No. 13-D Structure-Oriented Adaptive Gaussian Pyramid for Seismic Multiscale Fracture DetectionIEEE Geoscience and Remote Sensing Letters, Vol. 20Analysis of Neural Network Architectures for Semantic Segmentation of Seismic Data20 August 2023Fault identification based on the KPCA-GPSO-SVM algorithm for seismic attributes in the Sihe Coal Mine, Qinshui Basin, ChinaKe Ren, Guangui Zou, Suping Peng, Hen-Geul Yeh, Bowen Deng, and Yin Ji24 October 2022 | Interpretation, Vol. 0, No. jaRapid fault extraction from seismic images via deep learningJournal of Electronic Imaging, Vol. 31, No. 05Fault detection by skeleton extraction based on orientation field consistency15 July 2022 | PLOS ONE, Vol. 17, No. 7AN OVERVIEW OF SEISMIC ATTRIBUTES1 July 2022Decoding of seismic data for complex stratigraphic traps revealing by seismic attributes analogy in Yidma/Alamein concession area Western Desert, Egypt24 June 2022 | Journal of Petroleum Exploration and Production Technology, Vol. 14Multi-Scale Natural Fracture Prediction in Continental Shale Oil Reservoirs: A Case Study of the Fengcheng Formation in the Mahu Sag, Junggar Basin, China23 May 2022 | Frontiers in Earth Science, Vol. 10Application of Gradient Structure Tensor Attributes in Gas Cloud Area Recognition8 September 2022Strato-structural evolution of the deep-water Orange Basin: constraints from 3D reflection seismic data18 November 2022 | Solid Earth, Vol. 13, No. 11Faulted feature detection in a tight sand gas reservoir based on steerable pyramid votingXiaoqing Cui, Xuri Huang, Tiansheng Chen, Yungui Xu, and Chaozheng Xiao1 September 2021Machine seismic: an automatic approach for the identification of subsurface structural models27 March 2021 | Soft Computing, Vol. 25, No. 13Which seismic attributes are best for subtle fault detection?Marwa Hussein, Robert R. Stewart, and Jonny Wu4 May 2021 | Interpretation, Vol. 9, No. 2Geophysical Methods, Exploration and Analysis25 May 2021Overview of Seismic Attributes and Seismic Object Extraction21 February 2022Improving fault delineation using maximum entropy multispectral coherenceBin Lyu, Jie Qi, Saurabh Sinha, Jianjun Li, and Kurt J. Marfurt12 October 2020 | Interpretation, Vol. 8, No. 4Iterative geostatistical seismic inversion incorporating local anisotropies20 May 2020 | Computational Geosciences, Vol. 24, No. 4Time-migration velocity estimation using Fréchet derivatives based on nonlinear kinematic migration/demigration solvers17 January 2020 | Studia Geophysica et Geodaetica, Vol. 64, No. 1Hierarchical Approach to Modeling Karst and Fractures in Carbonate Karst Reservoirs in the Tarim Basin11 November 2019Vector attributes: A family of advanced seismic attributes to assist in geological interpretationAicha Bounaim, Marie Etchebes, Jarle Haukås, Hilde Borgos, Bjørn Harald Fotland, and Lars Sonneland10 August 2019Interpretation of the tectonic evolution of the western part of the Sava Depression: structural analysis of seismic attributes and subsurface structural modeling19 September 2019 | Journal of Maps, Vol. 15, No. 2Fracture networks based on Seismic Attributes Applications: A case study of fractured basement in the Malay BasinA.A.S Shamsuddin , N.H. Ngoc , S. Shahar , and P.G. Ghosh 29 April 2019Gaussian Markov Random Fields-Based Features for Volumetric Texture SegmentationValidated artificial neural networks in determining petrophysical properties: A case study from ColombiaUrsula Iturrarán-Viveros, Andrés M. Muñoz-García, Jorge O. Parra, and Josué Tago24 October 2018 | Interpretation, Vol. 6, No. 4Seismic facies analysis using machine learningThilo Wrona, Indranil Pan, Robert L. Gawthorpe, and Haakon Fossen5 September 2018 | GEOPHYSICS, Vol. 83, No. 5Classifying geological structure elements from seismic images using deep learningWeichang Li27 August 2018Coherence based on spectral variance analysisYanting Duan, Chaodong Wu, Xiaodong Zheng, Yucheng Huang, and Jian Ma9 April 2018 | GEOPHYSICS, Vol. 83, No. 3References19 January 2018Plane-wave Sobel attribute for discontinuity enhancement in seismic imagesMason Phillips and Sergey Fomel23 October 2017 | GEOPHYSICS, Vol. 82, No. 6Structure-oriented edge-preserving smoothing in the frequency domain: Application to enhance 3D seismic data volumesA texture-based interpretation workflow with application to delineating salt domesMuhammad Amir Shafiq, Zhen Wang, Ghassan AlRegib, Asjad Amin, and Mohamed Deriche2 March 2017 | Interpretation, Vol. 5, No. 3Fault detection using principal component analysis of seismic attributes in the Bakken Formation, Williston Basin, North Dakota, USAIsmot Jahan, John Castagna, Michael Murphy, and M. Amin Kayali19 May 2017 | Interpretation, Vol. 5, No. 3Discontinuity detection in compression salt tectonics and synkinematic strataQingzhen Wang, Jinmiao Zhang, Zhenyu Zhu, Xiudi Jiang, and Bin Weng17 August 2017Well-log interpolation guided by geologic distanceYunzhi Shi, Xinming Wu, and Sergey Fomel17 August 2017A structure-guided and edge-preserving algorithm for smoothing 3D seismic dataJulián L. Gómez, Danilo R. Velis, and Juan I. Sabbione3 August 2017Fault visualization and identification in fault seismic attribute volumes: Implications for fault geometric characterizationAudun Libak, Behzad Alaei, and Anita Torabi8 March 2017 | Interpretation, Vol. 5, No. 2Fault enhancement and visualization with 3D log-Gabor filter arrayYingwei Yu1 September 2016Depiction of delta boundaries using multiple seismic attributes based on 2D structure-oriented filtering and KL transformDa Peng and Cheng Yin1 September 2016Structure-oriented plane-wave Sobel filter for edge detection in seismic imagesMason Phillips, Sergey Fomel, and Ryan Swindeman1 September 2016A comparison of alternative volumetric dip computationsMegan Gunther and Kurt Marfurt1 September 2016Texture Attribute Analysis of GPR Data for Archaeological Prospection18 July 2016 | Pure and Applied Geophysics, Vol. 173, No. 8Quantifying the significance of coherence anomaliesTengfei Lin, Thang Ha, Kurt J. Marfurt, and Kevin L. Deal18 April 2016 | Interpretation, Vol. 4, No. 2References26 September 2016Semblance, coherence, and other discontinuity attributesJoe Kington1 December 2015 | The Leading Edge, Vol. 34, No. 12Fracture enhancement based on artificial ants and fuzzy c-means clustering (FCMC) in Dezful Embayment of Iran10 March 2015 | Journal of Geophysics and Engineering, Vol. 12, No. 2Seismic feature extraction using steiner tree methodsDictionary Based Segmentation in Volumes9 June 2015Paleokarst in the Grosmont Formation and reservoir implications, Saleski, Alberta, CanadaJen Russel-Houston and Ken Gray18 July 2014 | Interpretation, Vol. 2, No. 3Automatic fault localization using the generalized Earth Mover's distanceThe new method of seismic attributes extraction and fault detection based on the rotating rhombus methodLi Jun*, Zhang Junhua, Zhu Wenbo, Liu Xiantai, and Wu Gang24 April 2014Attribute illumination of basement faults, examples from Cuu Long Basin basement, Vietnam and the Midcontinent, USAHa T. Mai, Olubunmi O. Elebiju, and Kurt J. Marfurt11 February 2014 | Interpretation, Vol. 2, No. 1Enhancement of large faults with a windowed 3D Radon transform filterTrond Hellem Boe25 October 2012Integrated seismic texture segmentation and cluster analysis applied to channel delineation and chert reservoir characterizationMarcilio Castro de Matos, Malleswar (Moe) Yenugu, Sipuikinene Miguel Angelo, and Kurt J. Marfurt14 November 2011 | GEOPHYSICS, Vol. 76, No. 5Discontinuous seismic horizon tracking based on a poisson equation with incremental dirichlet boundary conditionsChannel delineation and chert reservoir characterization by integrated seismic texture segmentation and cluster analysisMarcilio Castro de Matos*, Malleswar (Moe) Yenugu, Kurt J. Marfurt, and Sipuikinene Miguel Angelo13 March 2014Salt diapirs without well defined boundaries – a feasibility study of semi‐automatic detection4 April 2011 | Geophysical Prospecting, Vol. 59, No. 4Latest developments in seismic texture analysis for subsurface structure, facies, and reservoir characterization: A reviewDengliang Gao17 March 2011 | GEOPHYSICS, Vol. 76, No. 2Integration of coherence and volumetric curvature imagesSatinder Chopra and Kurt J. Marfurt7 September 2010 | The Leading Edge, Vol. 29, No. 9Volumetric dips and azimuth of pre‐stack seismic data using the gradient structure tensorPascal Klein and Loic Richard21 October 2010Edge preserving vector filter for smoothing reflector dip and azimuthWei Wang, Jinghuai Gao, Hui Zheng, Wenchao Chen, and Erhua Zhang21 October 2010Structure-oriented Gaussian filter for seismic detail preserving smoothingSeismic fault detection using marked point processesFlow Unit Characterization and Geo-modeling of a Structurally Complex Fluvio-deltaic Reservoir using an Integrated Approach15 March 2009Structure‐adaptive anisotropic filter for seismic detail preserving smoothingWei Wang, Jinghuai Gao, Xiaokai Wang, and Yangyang He14 October 2009Data mining for large scale 3D seismic data analysis15 November 2007 | Machine Vision and Applications, Vol. 20, No. 1Inverse-vector approach for smoothing dips and azimuthsYuchun Eugene Wang, Yi Luo, and Mohammed Alfaraj15 October 2008 | GEOPHYSICS, Vol. 73, No. 6Seismic Fault Detection Based on a Curvilinear SupportRetrieving scale from quasi-stationary imagesPattern Recognition Letters, Vol. 29, No. 6Attribute illumination of basement faults, Cuu Long Basin, VietnamHa T. Mai and Kurt J. Marfurt15 December 2008New fault attribute based on robust directional schemeMarc Donias, Ciprian David, Yannick Berthoumieu, Olivier Lavialle, Sebastien Guillon, and Noomane Keskes9 May 2007 | GEOPHYSICS, Vol. 72, No. 43. Coherence21 March 2012Volumetric Texture Segmentation by Discriminant Feature Selection and Multiresolution ClassificationIEEE Transactions on Medical Imaging, Vol. 26, No. 1Segmentation of complex geophysical structures with well data20 October 2006 | Computational Geosciences, Vol. 10, No. 4From 3D Seismic Facies to Reservoir Simulation: An Example From the Grane FieldAtlas of 3D Seismic AttributesThe Use of Structure Tensors in the Analysis of Seismic DataAutomatic Fault Extraction Using Artificial AntsGeological Model Building: A Hierarchical Segmentation ApproachMapping 3D Geo-Bodies Based on Level Set and Marching MethodsAutomated mapping of carbonate build-ups and palaeokarst from the Norwegian Barents Sea using 3D seismic texture attributes11 May 2022 | Geological Society, London, Petroleum Geology Conference Series, Vol. 6, No. 1Fast structural interpretation with structure‐oriented filteringGijs C. Fehmers and Christian F. W. Höcker4 August 2003 | GEOPHYSICS, Vol. 68, No. 4New paradigm of fault interpretationStein Inge Pedersen, Thorleif Skov, Arne Hetlelid, Pauline Fayemendy, Trygve Randen, and Lars Sønneland3 January 2005Automatic extraction of fault surfaces from three‐dimensional seismic dataTrygve Randen, Stein Inge Pedersen, and Lars Sønneland3 January 2005Towards robust structure-based enhancement and horizon picking in 3-D seismic dataVolumetric Texture Analysis in Biomedical Imaging SEG Technical Program Expanded Abstracts 2000 ISSN (print):1052-3812 ISSN (online):1949-4645 Copyright: 2000 Pages: 2484 publication data© 2000 Copyright © 2000 Society of Exploration GeophysicistsPublisher:Society of Exploration Geophysicists HistoryPublished Online: 04 Jan 2005 CITATION INFORMATION Trygve Randen, Erik Monsen, Claude Signer, Arve Abrahamsen, Jan Ove Hansen, Toril Sæter, and Jürgen Schlaf, (2000), "Three‐dimensional texture attributes for seismic data analysis," SEG Technical Program Expanded Abstracts : 668-671. https://doi.org/10.1190/1.1816155 Plain-Language Summary PDF DownloadLoading ...

Summary This paper discusses the effects of various perforation and reservoir parameters on the productivity (or injectivity) of perforated completions. Because of the complex, 3D flow into a spiral system of perforations, productivity analysis of perforated completions is not easily amenable to analytical treatment. This paper presents a semianalytical solution for the estimation of skin in perforated completions. Results are presented for two separate cases: the 2D-plane-flow problem, which is essentially valid at small dimensionless perforation spacings (large perforation penetrations or high perforation shot densities) and the general 3D problem, where the vertical convergent flow into perforations is significant. In these analyses, the wellbore and vertical-flow effects are quantified in terms of pseu-doskins obtained by accurate finite-element simulations. The effects of perforation damage and formation anisotropy are also included. The results provide a better understanding of the relative role of various perforation parameters in affecting well productivity. Because they are based on theoretical considerations, the correlations allow reliable estimates of the skin in perforated completions. New relations are provided for estimating productivity of perforated completions with formation permeability damage. Results indicate the importance of angular phasing, in addition to perforation penetration, in overcoming the effects of formation damage on well productivity.

Abstract Three-component measurements of particle motion would bring significant benefits to towed-marine seismic data if processed in conjunction with the pressure data. We show that particle velocity measurements can increase the effective Nyquist wavenumber by a factor of two or three, depending on how they are used. A true multicomponent streamer would enable accurate data reconstruction in the crossline direction with cable separations for which pressure-only data would be irrecoverably aliased. We also show that conventional workflows aimed at reducing these aliasing effects, such as moveout correction applied before interpolation, are compatible with multicomponent measurements. Some benefits of velocity measurements for deghosting data are well known. We outline how the new measurements might be used to address some long-standing deghosting challenges of particular interest. Specifically, we propose methods for recovering de-ghosted data between streamers and for 3D deghosting of seismic data at the streamer locations.

Abstract Conventional amplitude inversion assumes that the migrated image preserves relative-amplitude information. However, illumination effects caused by complex geologic settings, undersampled acquisition geometry, and limited recording aperture pose a challenge to even the most advanced imaging algorithms. In addition, standard depth-migration images can suffer from lack of resolution caused by wavelet stretch, attenuation, and suboptimal deghosting. Least-squares migration (LSM) can mitigate many of these problems and produce better resolved migration images suitable for AVO inversion. However, whether formulated in the data domain or the image domain, LSM is an inversion algorithm and is sensitive to inaccuracies in the source wavelet, velocity model, data preprocessing, and the propagator used. Practical considerations to mitigate these problems under nonideal conditions and cost-reduction strategies differ between the data- and image-domain formulations. The relative merits of each approach are evaluated by using example inversions for complex synthetic models, including free-surface ghost and attenuation effects. When a data-domain implementation of LSM is considered necessary, the image-domain implementation should be considered at the same time, especially when targeting localized reservoir targets under complex overburdens. Application of image-domain least-squares migration on a Gulf of Mexico field data set produces significant improvements in resolution and event continuity in the subsalt target region.