Relevant bibliographies by topics / AVO

Contents

  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'AVO'

Author: Grafiati
Published: 4 June 2021
Last updated: 1 April 2023

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Journal articles on the topic "AVO"

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Ross, Christopher P. "Comparison of popular AVO attributes, AVO inversion, and calibrated AVO predictions." Leading Edge 21, no. 3 (March 2002): 244–52. http://dx.doi.org/10.1190/1.1463776.

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Colbeck, Carol L., and Robert Drago. "Accept avo." Change: The Magazine of Higher Learning 37, no. 6 (November 2005): 10–17. http://dx.doi.org/10.3200/chng.37.6.10-17.

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Simmons, James L., and Milo M. Backus. "Waveform‐based AVO inversion and AVO prediction‐error." GEOPHYSICS 61, no. 6 (November 1996): 1575–88. http://dx.doi.org/10.1190/1.1444077.

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A practical approach to linear prestack seismic inversion in the context of a locally 1-D earth is employed to use amplitude variation with offset (AVO) information for the direct detection in hydrocarbons. The inversion is based on the three‐term linearized approximation to the Zoeppritz equations. The normal‐incidence compressional‐wave reflection coefficient [Formula: see text] models the background reflectivity in the absence of hydrocarbons and incorporates the mudrock curve and Gardner’s equation. Prediction‐error parameters, [Formula: see text] and [Formula: see text], represent perturbations in the normal‐incidence shear‐wave reflection coefficient and the density contribution to the normal incidence reflectivity, respectively, from that predicted by the mudrock curve and Gardner’s equation. This prediction‐error approach can detect hydrocarbons in the absence of an overall increase in AVO, and in the absence of bright spots, as expected in theory. Linear inversion is applied to a portion of a young, Tertiary, shallow‐marine data set that contains known hydrocarbon accumulations. Prestack data are in the form of angle stack, or constant offset‐to‐depth ratio, gathers. Prestack synthetic seismograms are obtained by primaries‐only ray tracing using the linearized approximation to the Zoeppritz equations to model the reflection amplitudes. Where the a priori assumptions hold, the data are reproduced with a single parameter [Formula: see text]. Hydrocarbons are detected as low impedance relative to the surrounding shales and the downdip brine‐filled reservoir on [Formula: see text], also as positive perturbations (opposite polarity relative to [Formula: see text]) on [Formula: see text] and [Formula: see text]. The maximum perturbation in [Formula: see text] from the normal‐incidence shear‐wave reflection coefficient predicted by the a priori assumptions is 0.08. Hydrocarbon detection is achieved, although the overall seismic response of a gas‐filled thin layer shows a decrease in amplitude with offset (angle). The angle‐stack data (70 prestack ensembles, 0.504–1.936 s time range) are reproduced with a data residual that is 7 dB down. Reflectivity‐based prestack seismograms properly model a gas/water contact as a strong increase in AVO and a gas‐filled thin layer as a decrease in AVO.
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Beretta, Matteo Mario, Giancarlo Bernasconi, and Giuseppe Drufuca. "AVO and AVA inversion for fractured reservoir characterization." GEOPHYSICS 67, no. 1 (January 2002): 300–306. http://dx.doi.org/10.1190/1.1451802.

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Seismic wave reflection amplitudes are used to detect fluids and fracture properties in reservoirs. This paper studies the characterization of a vertically fractured fluid‐filled reservoir by analyzing the reflection amplitudes of P‐waves with varying incident and azimuthal angles. The reservoir is modeled as a horizontal transversely isotropic medium embedded in an isotropic background, and the linearized P‐waves reflection coefficient are considered. The conditioning of the inverse problem is analyzed, and fracture density is found to be the best conditioned parameter. Using diffraction tomography under the Born approximation, an inversion procedure is proposed in the transformed k–ω domain to detect fracture density variations within the reservoir. Seismic data are rearranged in pairs of incident and reflected plane waves, enlightening only one spectral component of the fracture density field at a time. Only the observable spectral components are inverted. Moreover, working in the transformed domain, picking reflection amplitudes is not required. An example of the inversion applied to a synthetic data set is presented. The limitation of source and receiver numbers and the finite bandwidth of the wavelet produce a loss of resolution, but the overall fracture density variations are recovered correctly.
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Mahob, Patrice Nsoga, and John P. Castagna. "AVO polarization and hodograms: AVO strength and polarization product." GEOPHYSICS 68, no. 3 (May 2003): 849–62. http://dx.doi.org/10.1190/1.1581037.

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An alternative approach to identifying amplitude‐variation‐with offset (AVO) anomalies is to consider the AVO polarization in the AVO intercept–AVO gradient (A‐B) plane. This method does not require deviations or separations from a background trend exhibited in traditional crossplots such as intercept‐gradient (A‐B) or near trace–far trace (N‐F). A benefit of the hodogram or polarization method is that the wavelet is taken into consideration. Crossplotted intercept and gradient are polarized along a “background trend” for nonanomalous events and at angles different from the “background trend” for anomalous events. This allows recognition of anomalous behavior otherwise buried in a background. Attributes resulting from this methodology include (1) the polarization angle, (2) the polarization angle difference, (3) the AVO strength, (4) the polarization product, and (5) the linear‐correlation coefficient. These different attributes can then be used to enhance AVO interpretation. Synthetic modeling for a succession of gas and brine layers encased in shale units indicates that the method can potentially be an effective hydrocarbon indicator. Application of the method to a real seismic dataset shows polarization anomalies associated with hydrocarbons.
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Ross, Christopher P. "Unbiased AVO crossplotting?" Leading Edge 35, no. 4 (April 2016): 338–44. http://dx.doi.org/10.1190/tle35040338.1.

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Ramos, Antonio C. B. "AVO processing calibration." Leading Edge 17, no. 8 (August 1998): 1075. http://dx.doi.org/10.1190/1.1438093.

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Ursin, Bjørn, and Bjørn Olav Ekren. "Robust AVO analysis." GEOPHYSICS 60, no. 2 (March 1995): 317–26. http://dx.doi.org/10.1190/1.1443768.

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Amplitude variation with offset (AVO) analysis is sensitive to errors in the moveout correction. To reduce moveout errors, AVO‐effects are estimated using time windows. For each time window, block‐NMO is used to avoid NMO‐stretch, and correction for residual NMO is performed by an iterative cross‐correlation technique. The data in a moveout‐corrected time window are modeled as a constant pulse multiplied by an amplitude function that is approximated by a polynomial in the offset coordinate. Conversion of data from offset to angle, or slowness, is therefore avoided. The seismic pulse and the polynomial coefficients are found by the least‐squares method. This is a separable least‐squares problem and the polynomial coefficients and the pulse can be estimated separately. The reduced nonlinear optimization problem for the coefficients is expressed as a Rayleigh quotient, providing the solution in one step. Once the coefficients have been found, the estimate of the pulse is computed by an explicit formula. This gives an efficient computational scheme. The method is demonstrated on a shallow seismic anomaly in the Barents Sea, offshore northern Norway.
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Ross, C. P. "Incomplete AVO near Salt Structures and Impact for AVO Analysis." Energy Exploration & Exploitation 10, no. 4-5 (September 1992): 335–53. http://dx.doi.org/10.1177/014459879201000410.

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Amplitude versus offset (AVO) measurements for deep hydrocarbon-bearing sands can be compromised when made in close proximity to a shallow salt piercement structure. Anomalous responses are observed, particularly on low acoustic impedance bright spots. Common-midpoint (CMP) data from key seismic profiles traversing the bright spots do not show the expected Class 3 offset responses as defined by Rutherford and Williams (1989). On these CMPs, significant decrease of far trace energy is observed. CMP data from other seismic profiles off-structure do exhibit the Class 3 offset responses, implying that structural complications may be interfering with the offset response. A synthetic AVO gather was generated using well log data, which supports the off-structure Class 3 responses, further reinforcing the concept of structurally-biased AVO responses. Acoustic, pseudo-spectral modelling of the structure substantiates the misleading AVO response. Pseudo-spectral modelling results suggest signal degradation observed on the far offsets is caused by wavefield refraction — a shadow zone, where the known hydrocarbon-bearing sands are not completely illuminated. Such shadow zones obscure the correct AVO response, which may have bearing on exploration and development.
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Tygel, Martin, Lúcio T. Santos, Jörg Schleicher, and Peter Hubral. "Kirchhoff imaging as a tool for AVO/AVA analysis." Leading Edge 18, no. 8 (August 1999): 940–45. http://dx.doi.org/10.1190/1.1438413.

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Dissertations / Theses on the topic "AVO"

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Buland, Arild. "Bayesian Seismic AVO Inversion." Doctoral thesis, Norwegian University of Science and Technology, Department of Mathematical Sciences, 2002. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-2005.

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Seismic analysis is a key element in successful exploration and production of natural resources. During the last decades, seismic methodology has had a significant progress with respect to both acquisition, processing and analysis. Despite all the new tec hnology, the uncertainty related to seismic analysis is still large, and even worse, the uncertainty is often not systematically assessed.

In this thesis, the uncertainty aspect of seismic amplitude versus offset (AVO) in version is assessed using a Bayesian approach to inversion. The main objective is to estimate elastic material parameters with associated uncertainty from large seismic data sets, but the in versionproblem also includes estimation of seismic wavelets and the noise level. State of the art statistical methodology is applied to attack these current and crucial geophysical problems. The core part of the work is presented in four separate papers written for geophysical journals, constituting Chapter 2 through 5 in this thesis. Each of the papers is self-contained, with exception of the references which are placed in a separate bibliography chapter.


Paper I, II and III: copyright SEG Paper III: copyright EAGE
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Gislason, Gardar. "Effect of Petrophysical Parameters on Seismic Waveform Signatures : Review of Theory with Case Study from Frigg Delta Oil Field, Norway." Thesis, Uppsala universitet, Geofysik, 2016. http://urn.kb.se/resolve?urn=urn:nbn:se:uu:diva-303793.

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Conventional AVO analysis has been used for the past 4 decades to aid in locating oil and gas reservoirs for extraction. It is, however, not possible to use it to acquire information on the porosity of the rock, the fluid saturation or other important petrophysical parameters. In this thesis, I study the effects of attenuation on seismic waveform signatures, due to wave induced fluid-flow. In the first part of the thesis, 2 models were used to synthetically model the attenuation caused by the wave induced fluid-flow: White's model and the double-porosity dual-permeability (DPDP) model. The parameters used for modeling were both synthetic and acquired from real well data of a known oil field off the coast of Norway. White's model was found to model relatively high attenuation (5%) for intermediately consolidated gas reservoirs while oil saturated intermediately consolidated reservoirs showed such low attenuation (0.3%) that it is easy to say that for the real-world situation it would not be detected. The DPDP model seemed to be able to better describe the attenuation and gave attenuations up to 10% for an intermediately consolidated oil reservoir, but due to lack of parameters from well data it was not sufficiently able to model the real-world situation. The synthetic data, however, show interesting characteristics and it is therefore recommended that more and detailed well parameters be acquired if the research should continue. For the second part, Svenska Petroleum Exploration AB and Det Norske Oljeselskap ASA provided stacked seismic data that were spectrally analyzed for hints of attenuation variation with frequency (using Fourier Transform and Complex Spectral Decomposition). Twelve locations, on the stacked seismic cube, were analyzed; six oil saturated; and six (assumed) water saturated. At each location, a main trace was selected along with the two nearby traces on each side of it (five in total). The Complex Spectral Decomposition method seemed unable to correctly break down the stacked section's signal, which is why Fourier Transform was used for further analysis. The frequency analysis showed a peak at ~30 Hz for both oil and water saturated reservoirs which seems like a characteristic frequency of the source, but that was unfortunately not confirmed and not enough time was available to test the assumption. The Fourier transform seems to show some difference between oil and water saturated traces, but that could well be because of lithological differences and not the pore fluid. It is therefore recommended, if research is to be continued, that 4D seismic data is used to analyze the same location with respect to time. It is also recommended that pre-stack or shot data be used as information is lost in stacked data.
Konventionell AVO-analys har använts under fyra deceniär som ett hjälpmedel för att finna olje- och gasreserver, men tekniken kan även användas för att erhålla information om bergets porositet, vätskemättnaden och andra viktiga petrofysiska parametrar. I denna avhandlingen har jag studerat hur våginducerat vätskeflöde påverkar dämpningen av den seismiska vågformssignaturen. I den första delen av avhandlingen användes två metoder för att syntetisk modellera dämpning orsakad av våginducerat vätskeflöde: "White's modell" och "double-porosity dual-permeability (DPDP) modellen". Både syntetiska parametrar och verkliga parametrar från borrhålsdata från ett känt norskt oljefält användes vid modelleringen. White's modell visade sig modellera relativt kraftig dämpning (5%) för medelstarkt konsoliderade gasreservoarer medan för oljereservoarer med motsvaranda konsolidering dämpningen var så låg (0.3%) att det är uppenbart att i en verklig situation skulle dämpningen inte vara mätbar. DPDP modelleringen verkar vara bättre på att beskriva dämpningen och gav dämpningar upp till 10% för en medelstarkt konsoliderad oljereservoar. Brist på parametrar från borrhålsdata gjorde att det inte var möjligt att på ett tillfredställande sätt modellera en verklig situation.Dock visade syntetisk data intressant karaktäristik och det rekommenderas därför att mer och detaljerade borrhålsparametrar mäts om ytterligare forskning om detta ska genomföras. För den andra delen av avhandlingen har Svenska Petroleum Exploration AB och Det Norske Oljeselskap ASA bidragit med stackad seismisk data som även var spectralanalyserad för indikationer på frekvensberoende dämpningsvariationer (utfört med fouriertransform och komplex spectraldekomposition). Tolv områden på den stackade kuben analyserades; sex oljemättade och sex som antogs vara vattenmättade. I varje område valdes en huvudtracé och de två närmaste tracéerna på vardera sida (totalt fem tracéer). Metoden med komplex spectraldekomposition klarade inte att analysera signalen från den stackade sektionen, varför fouriertransform användes för vidare analys. Frekvensanalysen gav en topp vid ~30 Hz för både olje- och vattenmättade reservoarer vilket tycks vara en karaktäristisk frekvens för källan. Detta kunde tyvärr inte bekräftas och tiden räckte inte till för att testa antagandet. Fouriertransformen tycks visa en viss skillnad mellan olje- och vattenmättade tracéer, men det kan också bero på skillnad i litologin snarare än porvätskan. Där för rekommenderas vid fortsättning på denna forskning att 4D seismisk data används för att analysera samma område men med data från olika tidpunkter. Det rekommenderas även att ostackad eller råa skott-data används eftersom väsentlig information kan försvinna när data stackas.

Advisor present: Dr. Chris Juhlin

Examiner: Dr. Milovan Urosevic

Opponent: Álvaro Polín Tornero

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Skopintseva, Lyubov. "Exploring the potential of long offset reflections in AVO inversion and AVO analysis." Doctoral thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2011. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-15380.

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Analysis of seismic reflection amplitudes versus offset (AVO) is one of common techniques widely exploited in the industry for reservoir characterization. For the last two decades a lot of approaches to analysis, inversion and interpretation of AVO data have been developed. Existing modifications valid for weak-contrast interfaces were successfully employed for conventional reservoirs. The growing interest of the industry to unconventional reservoirs, such as stiff-carbonate reservoirs, heavy oil traps and reservoirs close to salts domes - associated with strong-contrast interfaces and critical angles - implies the development of AVO techniques valid prior and beyond the critical angle. It has been reported in literature that near- and post-critical reflections have a potential to be employed as an additional source of information about the media. However, the use of these reflections is limited by the inability of well-known Zoeppritz equations to explain phenomena observed around and beyond the critical angle. The aim of the thesis is to investigate phenomena observed at the reflected data around and beyond the critical angle, understand their potential from the AVO analysis and inversion point of view and develop a long-offset AVO inversion approach valid for strong-contrast interfaces. The theory of effective reflection coefficients is exploited as a mathematical apparatus providing an adequate description of phenomena observed at near- and post-critical reflections. The thesis consists of five papers, where four major issues are addressed. The sensitivity of the reflection coefficient to isotropic and HTI media parameter changes prior to and beyond the critical angle is studied. The long-offset AVO inversion approach valid prior to and beyond the critical angle, strong-contrast and curved interfaces is developed and tested on synthetic data obtained for models with a single interface of various curvatures. Frequency effects in pre- near- and post-critical domains observed on the data of physical modeling are studied from the point of view of potential exploiting. Finally, the sensitivity of long-offset AVO inversion to errors related to overburden velocity misinterpretation is analyzed.
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Ross, Christopher P. "AVO limitations near salt structures." Diss., Georgia Institute of Technology, 1992. http://hdl.handle.net/1853/31010.

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Alhussain, Mohammed. "Spherical wave AVO response of isotropic and anisotropic media: Laboratory experiment versus numerical simulations." Thesis, Curtin University, 2007. http://hdl.handle.net/20.500.11937/267.

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A spherical wave AVO response is investigated by measuring ultrasonic reflection amplitudes from a water/Plexiglas interface. The experimental results show substantial deviation from the plane-wave reflection coefficients at large angles. However there is an excellent agreement between experimental data and full-wave numerical simulations performed with the reflectivity algorithm. By comparing the spherical-wave AVO response, modeled with different frequencies, to the plane-wave response, I show that the differences between the two are of such magnitude that three-term AVO inversion based on AVA curvature can be erroneous. I then propose an alternative approach to use critical angle information extracted from AVA curves, and show that this leads to a significant improvement of the estimation of elastic parameters. Azimuthal variation of the AVO response of a vertically fractured model also shows good agreement with anisotropic reflectivity simulations, especially in terms of extracted critical angles which indicated that (1) reflection measurements are consistent with the transmission measurements; (2) the anisotropic numerical simulation algorithm is capable of simulating subtle azimuthal variations with excellent accuracy; (3) the methodology of picking critical angles on seismograms using the inflection point is robust, even in the presence of random and/or systematic noise.
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Ivanov, Elena. "A feasibility study of three term AVO /." Title page, abstract and table of contents only, 2002. http://web4.library.adelaide.edu.au/theses/09SB/09sbi934.pdf.

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Shrestha, Rajendra K. "3-D AVO analysis : a novel approach /." Full-text version available from OU Domain via ProQuest Digital Dissertations, 1992.

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Alhussain, Mohammed. "Spherical wave AVO response of isotropic and anisotropic media: Laboratory experiment versus numerical simulations." Curtin University of Technology, Department of Exploration Geophysics, 2007. http://espace.library.curtin.edu.au:80/R/?func=dbin-jump-full&object_id=17537.

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A spherical wave AVO response is investigated by measuring ultrasonic reflection amplitudes from a water/Plexiglas interface. The experimental results show substantial deviation from the plane-wave reflection coefficients at large angles. However there is an excellent agreement between experimental data and full-wave numerical simulations performed with the reflectivity algorithm. By comparing the spherical-wave AVO response, modeled with different frequencies, to the plane-wave response, I show that the differences between the two are of such magnitude that three-term AVO inversion based on AVA curvature can be erroneous. I then propose an alternative approach to use critical angle information extracted from AVA curves, and show that this leads to a significant improvement of the estimation of elastic parameters. Azimuthal variation of the AVO response of a vertically fractured model also shows good agreement with anisotropic reflectivity simulations, especially in terms of extracted critical angles which indicated that (1) reflection measurements are consistent with the transmission measurements; (2) the anisotropic numerical simulation algorithm is capable of simulating subtle azimuthal variations with excellent accuracy; (3) the methodology of picking critical angles on seismograms using the inflection point is robust, even in the presence of random and/or systematic noise.
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Wilson, Adam. "Theory and methods of frequency-dependent AVO Inversion." Thesis, University of Edinburgh, 2010. http://hdl.handle.net/1842/4740.

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Amplitude-versus-offset, AVO, approximations allow the estimation of various properties from pre-stack seismic gathers. Recently it has been suggested that fluid mobility is a controlling factor in pore pressure equalisation and can result in anomalous velocity dispersion in the seismic bandwidth. However, current approximations all assume an elastic subsurface and are unable to account for velocity dispersion. I have applied existing methodologies to a real dataset to qualitatively detect and interpret spectral amplitude anomalies. Three areas had AVO and spectral signature consistent with frequency-dependent AVO theory. The results suggest that it is feasible to measure such effects on real data in the presence of random noise. It would imply that the relaxation parameter, tau, is larger in the field than has been measured in water-saturated real and synthetic sandstones in the laboratory. I extended a two-term AVO approximation by accounting for velocity dispersion and showed how the resultant reflection coefficient becomes frequency-dependent. I then used this to measure P- and S-wave reflectivity dispersion using spectrally-balanced amplitudes. The inversion was able to quantify the affect of the P-wave velocity dispersion as an instantaneous effect on the reflection. NMO stretch was an issue at the far offsets and I limited myself to the near offsets and effectively measured only the P-wave reflectivity dispersion. I showed how the P-wave reflectivity dispersion signs depend on the AVO classification of the reflection whilst the magnitude depends on the crack density of my model. I showed how the effect of noise and thin-bed tuning can enter uncertainties into the interpretation of spectral anomalies. Whilst it is possible to detect frequency-dependent AVO signatures on pre-stack gathers, the interpretation remains non-unique. I have quantitatively measured a new physical property, reflectivity dispersion, from pre-stack seismic data. I have presented a method of detecting and measuring velocity dispersion in pre-stack gathers but there remain ambiguities in the interpretation of such results. The approach incorporates spectrally decomposed data in an extended AVO inversion scheme. Future work should investigate the application of the methodology to a real seismic dataset.
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Ellison, Shelley J. "Modeling Offset-Dependent Reflectivity for Time-Lapse Monitoring of Water-Flood Production in Thin-Layered Reservoirs." Thesis, Virginia Tech, 2001. http://hdl.handle.net/10919/34058.

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Seismic time-lapse monitoring of production is an important tool used to efficiently drain a hydrocarbon reservoir. Repeat seismic surveys may be used, because the seismic method is sensitive to the reservoir fluid. A prominent seismic attribute is the reflectivity (or amplitude) as a function of offset (AVO) which strongly depends on material properties, and hence, on the pore fluid. Repeat surveys, however, are very costly. To reduce the risks, the repeat survey is simulated on a computer for a number of different scenarios. Hence, the objectives of this study are to predict the seismic responses after five years of production of the reservoirs at the well locations, correlate the seismic attributes to fluid conditions in the reservoirs, assess the detectability of changes in AVO attributes due to changes in fluid conditions, and determine which attribute is more diagnostic of fluid changes. Petrophysical models were generated for different pore fluids using well logs from a field in the Gulf of Mexico. Synthetic seismograms were then calculated using a layerstack scheme to study the effects of the reservoir fluids on AVO. Compared to idealized half-space models, it was found that the AVO responses are contaminated by the overburden and the thinness of the reservoir. In order to remove transmission loss due to overburden effects, the synthetic AVO curves were scaled by normalizing an overburden-over-half-space model to an idealized analytical Zoeppritz model. In a second step, an offset-dependent overburden correction was applied using a low order polynomial, which was fitted to the amplitude ratios between the overburden/half-space model and the idealized model. Finally, a zero-offset tuning correction was applied. The results of the AVO analyses showed that some errors were unresolved using the applied overburden and tuning corrections, and amplitudes at large offsets were possibly contaminated by multiples and converted waves. Since there is no shallower production or steam injection for this particular field, the repeat surveys should have the same overburden, tuning, multiple-related and converted wave contamination. It appears reasonable to assume that any changes in amplitude between the repeat surveys would be due to fluid saturation changes. Therefore, it was concluded that it is not necessary to attempt to remove the overburden and tuning effects. Results from the AVO analyses of the uncorrected models showed that AVO attributes should be a useful tool to detect reservoir conditions during the production of the field. Generally, the water-flood changes the AVO by decreasing the intercept and increasing the gradient from the in-situ oil/gas cases. The relative changes in both intercept and gradient due to the water-flood are detectable assuming a 20% relative-change detection threshold, and gradient is more diagnostic because the relative change in gradient is very large compared to that for intercept.
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Books on the topic "AVO"

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Shiloni, Raḥel. Levadi avo. Tel-Aviv: Milo, 1990.

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Shiloni, Raḥel. Levadi avo. Tel-Aviv: Milo, 1990.

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Avo beli aṿir. Or Yehudah: Zemorah-Bitan, 2012.

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Mehta, Yashvant. Avo Samjiye Vignan. India: Gurjar Granth, 1990.

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Meehta, Yashvant. Avo samjie vignan. Ahmedabad: Gurjar, 1990.

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Nalbandyan, Shushanik, and E. Hakobyan. Avo Hovhannisyan: Dardz armatnerin. Erevan: Heghinakayin hratarakutʻyun, 2012.

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Pelucchi, Giuliana. Proposta AVO: Per "umanizzare" la vita negli ospedali. Torino: Paoline, 1993.

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Seta, Melkonian, ed. Avo: Montʻe Melkʻonyani kyankʻě ev mahě. Erevan: Heghinakayin hratarakutʻyun, 2007.

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Gibson, Gwen. Avo kao: Pre-reading & writing workbook. Ukarumpa, Papua New Guinea: Summer Institute of Linguistics, 1995.

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Looveer, Avo-Himm. Arhitekt Avo-Himm Looveer: 1941-2002. [Tallinn]: Eesti Arhitektuurimuuseum, 2003.

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Book chapters on the topic "AVO"

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Cui, Xiaoqin, Laurence Lines, Edward Stephen Krebes, and Suping Peng. "Fractured Medium AVO Inversion." In Seismic Forward Modeling of Fractures and Fractured Medium Inversion, 95–122. Singapore: Springer Singapore, 2017. http://dx.doi.org/10.1007/978-981-10-3584-5_4.

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Upadhyay, S. K. "Reflection Amplitude and AVO-Interpretation." In Seismic Reflection Processing, 379–423. Berlin, Heidelberg: Springer Berlin Heidelberg, 2004. http://dx.doi.org/10.1007/978-3-662-09843-1_13.

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Azevedo, Leonardo, Pedro Correia, Rúben Nunes, and Amílcar Soares. "Geostatistical AVO Direct Facies Inversion." In Lecture Notes in Earth System Sciences, 565–69. Berlin, Heidelberg: Springer Berlin Heidelberg, 2013. http://dx.doi.org/10.1007/978-3-642-32408-6_124.

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Maurya, S. P., N. P. Singh, and K. H. Singh. "Amplitude Variation with Offset (AVO) Inversion." In Seismic Inversion Methods: A Practical Approach, 107–43. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-45662-7_5.

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Li, Xiaoting, Hongwei Wang, Suping Peng, Wenfeng Du, and Yingchuan Sun. "Improvement on AVO Equations in VTI Media." In Technology and Application of Environmental and Engineering Geophysics, 81–86. Singapore: Springer Singapore, 2017. http://dx.doi.org/10.1007/978-981-10-3244-8_9.

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D’Angelo, Richard M. "An AVO Study on North Sea Data." In North Sea Oil and Gas Reservoirs — III, 109–14. Dordrecht: Springer Netherlands, 1994. http://dx.doi.org/10.1007/978-94-011-0896-6_7.

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Łukaszewski, Tomasz, Jedrzej Potoniec, and Szymon Wilk. "Hypothesis-Driven Interactive Classification Based on AVO." In Advances in Intelligent Systems and Computing, 71–78. Cham: Springer International Publishing, 2014. http://dx.doi.org/10.1007/978-3-319-02309-0_7.

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Gullco, Robert S., and Malcolm Anderson. "Applications of rock physics to AVO analyses." In Elements of Rock Physics and Their Application to Inversion and AVO Studies, 95–117. London: CRC Press, 2021. http://dx.doi.org/10.1201/9781003261773-8.

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Changcheng, Liu. "A New Fluid Factor Based on AVO Technique." In ICIPEG 2014, 257–65. Singapore: Springer Singapore, 2015. http://dx.doi.org/10.1007/978-981-287-368-2_24.

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G. Allen, Mark, Paolo Padovani, Piero Rosati, and Nicholas A. Walton. "AVO FIRST SCIENCE Discovery of type 2 quasars." In The Many Scales in the Universe, 253–60. Dordrecht: Springer Netherlands, 2006. http://dx.doi.org/10.1007/1-4020-4526-3_21.

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Conference papers on the topic "AVO"

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Farfour, Mohammed, and Wang Jung Yoon. "Energy-weighted AVO: a new AVO attribute." In Proceedings of the 12th SEGJ International Symposium, Tokyo, Japan, 18-20 November 2015. Society of Exploration Geophysicists and Society of Exploration Geophysicists of Japan, 2015. http://dx.doi.org/10.1190/segj122015-022.

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Xiaodong, Zheng. "Linear AVO inversion and post‐AVO inversion." In SEG Technical Program Expanded Abstracts 1994. Society of Exploration Geophysicists, 1994. http://dx.doi.org/10.1190/1.1932052.

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Wrolstad, Keith H. "AVO representations." In SEG Technical Program Expanded Abstracts 1988. Society of Exploration Geophysicists, 1988. http://dx.doi.org/10.1190/1.1892541.

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Lin, T. L., and R. Phair. "AVO tuning." In SEG Technical Program Expanded Abstracts 1993. Society of Exploration Geophysicists, 1993. http://dx.doi.org/10.1190/1.1822600.

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Crosby, A. "AVO Sparklines." In 82nd EAGE Annual Conference & Exhibition. European Association of Geoscientists & Engineers, 2020. http://dx.doi.org/10.3997/2214-4609.202010883.

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Ellen Gomes, N. S., J. S. Protazio, J. C. Costa, and I. A. Simoes-Filho. "Ambiguity in AVO/AVD Analysis for Anisotropic Media." In 62nd EAGE Conference & Exhibition. European Association of Geoscientists & Engineers, 2000. http://dx.doi.org/10.3997/2214-4609-pdb.28.c10.

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Simőes-Filho, I. A. "Ambiguity In Avo/Ava Analysis For Anisotropic Media." In 6th International Congress of the Brazilian Geophysical Society. European Association of Geoscientists & Engineers, 1999. http://dx.doi.org/10.3997/2214-4609-pdb.215.sbgf214.

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Zillmer, Matthias, Dirk Gajewski, and Boris M. Kashtan. "P‐wave AVO/AVA for vertically fractured media." In SEG Technical Program Expanded Abstracts 1997. Society of Exploration Geophysicists, 1997. http://dx.doi.org/10.1190/1.1885817.

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Madsen, R. B., E. Nørmark, and T. Mejer Hansen. "Accounting for Processing Errors in AVO/AVA Data." In 80th EAGE Conference and Exhibition 2018. Netherlands: EAGE Publications BV, 2018. http://dx.doi.org/10.3997/2214-4609.201801347.

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Pérez, Daniel O., and Danilo R. Veils. "Sparse‐spike AVO/AVA attributes from prestack data." In SEG Technical Program Expanded Abstracts 2011. Society of Exploration Geophysicists, 2011. http://dx.doi.org/10.1190/1.3627906.

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Reports on the topic "AVO"

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Tsvankin, I. Body-wave radiation patterns and AVO in transversely isotropic media. Office of Scientific and Technical Information (OSTI), March 1994. http://dx.doi.org/10.2172/10137856.

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Deeds, Jake, and John Bradford. CHARACTERIZATION OF AN AQUITARD AND DIRECT DETECTION OF LNAPL AT HILL AIR FORCE BASE USING GPR AVO AND MIGRATION VELOCITY ANALYSES. Office of Scientific and Technical Information (OSTI), June 2002. http://dx.doi.org/10.2172/833500.

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Michalski, Ranny L. X. N., Bruno Masiero, William D’Andrea Fonseca, and Márcio Avelar. Fim do Ano Internacional do Som: Fechamento do Ano Internacional do Som 2020 & 2021. Revista Acústica e Vibrações, December 2021. http://dx.doi.org/10.55753/aev.v36e53.60.

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Abstract:
O Ano Internacional do Som (International Year of Sound — IYS) teve início em 2020 e foi prorrogado por mais um ano, em decorrência da pandemia da COVID-19. O presente artigo reúne informações sobre eventos e ações relacionados ao IYS que aconteceram no Brasil ao longo dos seus dois anos de duração.
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Cleveland, J. (AVR test program review). Office of Scientific and Technical Information (OSTI), June 1989. http://dx.doi.org/10.2172/5740310.

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Fleischman, E. WAVE and AVI Codec Registries. RFC Editor, June 1998. http://dx.doi.org/10.17487/rfc2361.

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King, William T. MURI/ARO Functionally Tailored Textiles. Fort Belvoir, VA: Defense Technical Information Center, August 2002. http://dx.doi.org/10.21236/ada412609.

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Anderson, B., L. Hagler, and S. Sitaraman. CASTOR THTR/AVR Containment Review. Office of Scientific and Technical Information (OSTI), July 2020. http://dx.doi.org/10.2172/1670542.

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Duncan, Victoria. ATO 1 - Health Physics Day. Office of Scientific and Technical Information (OSTI), August 2021. http://dx.doi.org/10.2172/1818083.

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SGC, Servicio Geológico Colombiano. Geología de la plancha 38 Carmen de Bolívar. Escala 1:100.000. Producto. Versión año año 1996. Bogotá: Servicio Geológico Colombiano, January 1996. http://dx.doi.org/10.32685/10.143.1996.241.

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SGC, Servicio Geológico Colombiano. Geología de la Plancha 365 Coconuco. Escala 1:100.000. Producto. versión año 2003. Versión digital año 2009. Bogotá: Servicio Geológico Colombiano, September 2003. http://dx.doi.org/10.32685/10.143.2003.253.

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