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Collaborating Authors
Chopra, Satinder
ABSTRACT Considering the importance of density for characterizing the conventional/unconventional plays, attempts have been made to compute it using vertical component seismic data as well as multicomponent seismic data for characterizing the Duvernay shale play in Alberta, Canada. Simultaneous inversion (PP) and PP-PS joint inversions were followed for density estimation as these are two conventional approaches considered usually for computing it from seismic data. Knowing the advantage of multicomponent data for deriving the different elastic parameters (P-impedance, S-impedance, density, Young’s modulus, Poisson’s ratio, etc.), prestack joint inversion results were compared with the simultaneous inversion. Though a better-quality estimation of P- and S-impedance is noticed with prestack joint inversion, this method is not able to provide a reliable estimation of density from seismic data. The reason for the multicomponent seismic data falling short of reliable determination of density is explored in this study. Thereafter, a novel approach for estimating reliable density attribute from seismic data is also proposed. Presentation Date: Wednesday, September 27, 2017 Start Time: 9:45 AM Location: Exhibit Hall C/D Presentation Type: POSTER
- Geology > Rock Type > Sedimentary Rock (1.00)
- Geology > Geological Subdiscipline > Geomechanics (0.69)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.55)
Integration of geomechanical and mineralogical data for fracability evaluation in Utica Shale play
Sharma, Ritesh (Arcis Seismic Solutions, TGS) | Chopra, Satinder (Arcis Seismic Solutions, TGS) | Nemati, M.Hossein (Arcis Seismic Solutions, TGS) | Keay, James (TGS) | Lines, Laurence (University of Calgary)
ABSTRACT The Utica shale extends across much of eastern US and as it possesses all the prerequisites of being a successful unconventional play, it has gained attention of the oil and gas industry. The high carbonate content of the target zone enables effective fracture stimulations, but the well performance along the Utica trend is variable; some strong producers are edged out by modest or low producing wells. Each well performance depends on how accurately horizontal drilling and multistage fracturing have been executed in the shale play. The efficiency of fracturing depends on many factors, but brittleness is one of the most important ones. However, there is no universally accepted indicator of brittleness. For the present study, mechanical as well as mineralogical attempts have been made to extract the brittleness information for the Utica play. While an attempt is made to determine brittleness from mechanical rock physics parameters (Young’s modulus and Poisson’s ratio) derived from seismic data, the available XRD data and regional petrophysical modelling make it possible to determine the brittleness index based on mineralogical data and thereafter be derived from seismic data. Presentation Date: Tuesday, September 26, 2017 Start Time: 3:55 PM Location: 330A Presentation Type: ORAL
- North America > United States > Ohio (1.00)
- North America > United States > West Virginia (0.86)
- North America > United States > Pennsylvania (0.86)
- (2 more...)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (0.86)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.54)
Seismic reservoir characterization of Duvernay shale with quantitative interpretation and induced seismicity considerations — A case study
Chopra, Satinder (Arcis Seismic Solutions) | Sharma, Ritesh Kumar (Arcis Seismic Solutions) | Ray, Amit Kumar (Arcis Seismic Solutions, Pandit Deendayal Petroleum University) | Nemati, Hossein (Arcis Seismic Solutions) | Morin, Ray (Repsol Oil and Gas Canada) | Schulte, Brian (Repsol Oil and Gas Canada) | D’Amico, David (Repsol Oil and Gas Canada)
Abstract The Devonian Duvernay Formation in northwest central Alberta, Canada, has become a hot play in the past few years due to its richness in liquid and gaseous hydrocarbon resources. The oil and gas generation in this shale formation made it the source rock for many oil and gas fields in its vicinity. We attempt to showcase the characterization of Duvernay Formation using 3D multicomponent seismic data and integrating it with the available well log and other relevant data. This has been done by deriving rock-physics parameters (Young’s modulus and Poisson’s ratio) through deterministic simultaneous and joint impedance inversion, with appropriate quantitative interpretation. In particular, we determine the brittleness of the Duvernay interval, which helps us determine the sweet spots therein. The scope of this characterization exercise was extended to explore the induced seismicity observed in the area (i.e., earthquakes of magnitude ) that is perceived to be associated with hydraulic fracture stimulation of the Duvernay. This has been a cause of media coverage lately. We attempt to integrate our results with the induced seismicity data available in the public domain and elaborate on our learning experience gained so far.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.69)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.66)
- North America > Canada > Saskatchewan > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Northwest Territories > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Manitoba > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- (7 more...)
Abstract The interpretation of faults on 3D seismic data is often aided by the use of geometric attributes such as coherence and curvature. Unfortunately, these same attributes also delineate stratigraphic boundaries (geologic signal) and apparent discontinuities due to cross-cutting seismic noise. Effective fault mapping thus requires enhancing piecewise continuous faults and suppressing stratabound edges and unconformities as well as seismic noise. To achieve this objective, we apply two passes of edge-preserving structure-oriented filtering followed by a recently developed fault enhancement algorithm based on a directional Laplacian of a Gaussian operator. We determine the effectiveness of this workflow on a 3D seismic volume from central British Columbia, Canada.
- North America > United States > Oklahoma (0.28)
- North America > Canada > British Columbia (0.24)
- Geology > Structural Geology > Fault (1.00)
- Geology > Geological Subdiscipline > Stratigraphy > Lithostratigraphy (0.35)
ABSTRACT While reflections associated with conformal sedimentary layers are usually coherent and continuous, other reflections such as mass transport complexes, karst collapse, and salt, may appear to be quite chaotic, without any specific orientation. We may also see chaotic events that have little to do with the target geology, but rather are artifacts due to variations in the overburden and surface or budget limitations resulting in a suboptimum acquisition program. While some of these artifact issues can be handled at the time of processing, a certain level of randomness remains in most seismic data volumes. Geologic features of interpretational interest such as fault damage zones, unconformities, and gas chimneys often have randomness associated with them, which can be characterized in terms of seismic disorder attribute amongst others. We demonstrate the application of seismic disorder attribute to two different datasets and find that it is a useful attribute for assessing the signal-to-noise ratio and data quality, in addition to helping delineate damage zones associated with large faults, and the interior of salt dome structures. Presentation Date: Monday, October 17, 2016 Start Time: 2:15:00 PM Location: Lobby D/C Presentation Type: POSTER
- North America > United States (0.29)
- North America > Canada > Alberta (0.16)
- Geology > Structural Geology (1.00)
- Geology > Rock Type > Sedimentary Rock (0.90)
- Geology > Geological Subdiscipline > Stratigraphy (0.68)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (0.89)
Characterizing a Cardium waterflood via 3-C–3D land surface seismic: The Washout Creek experience
Perz, Michael (TGS) | Chopra, Satinder (TGS) | Sharma, Ritesh (TGS) | Cary, Peter (TGS) | Li, Xinxiang (Arcis Seismic Solutions) | Ohlhauser, Wendy (Arcis Seismic Solutions) | Pike, Kimberly (PennWest) | Creaser, Brian (Enerplus) | Nemati, M. Hossein (Arcis)
ABSTRACT A high-effort, multicomponent 3C3D seismic data set was acquired over a mature oil field in central Alberta in order to better understand the characteristics of a waterflood operation. True-amplitude processing of the data was undertaken, and joint PP-PS prestack impedance inversion reveals a pronounced set of anomalous low-impedance lineaments at the target level which exhibit a very strong spatial correlation with known water injector locations. Rock physics modeling demonstrates that fluid pressure effects are heavily influencing the seismic response in the vicinity of the injectors, and are accounting for the observed low-impedance anomalies. Analysis of injection and production data suggests that the seismic data can play a vital role in identifying zones of unswept pay in this area. Presentation Date: Monday, October 17, 2016 Start Time: 1:00:00 PM Location: 156 Presentation Type: ORAL
- Europe (0.33)
- North America > Canada > Alberta (0.25)
- Geology > Geological Subdiscipline > Geomechanics (0.72)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.31)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Deep Basin > Cardium Formation (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5505/13 > Halfdan Field > Maastrichtian Formation (0.99)
- Europe > Denmark > North Sea > Danish Sector > Central Graben > Block 5505/13 > Halfdan Field > Danian Formation (0.99)
- (2 more...)
Seismic reservoir characterization of Duvernay shale with quantitative interpretation and induced seismicity considerations: A case study
Chopra, Satinder (TGS) | Sharma, Ritesh (TGS) | Ray, Amit (Reliance Industries Ltd) | Nemati, M. Hossein (Arcis Seismic Solutions, TGS) | Morin, Ray (Talisman Energy, Inc) | Schulte, Brian (Geokinetics Inc) | D'Amico, David (Repsol)
ABSTRACT The Devonian Duvernay Formation in northwest central Alberta, Canada has become a hot play in the last few years due to its richness in both liquid and gaseous hydrocarbon resources. The oil and gas generation in this shale formation made it the source rock for many oil and gas fields in its vicinity. This case study attempts to showcase the characterization of Duvernay Formation by using 3D multicomponent seismic data, and integrating it with the available well log and other relevant data. This characterization has been done by deriving rock physics parameters (Young’s modulus, Poisson’s ratio, etc.) through deterministic simultaneous and joint impedance inversion, with appropriate quantitative interpretation. In particular, we determine the brittleness of the Duvernay interval which helps us determine the sweet spots therein. The scope of this characterization exercise was extended to explore the induced seismicity observed in the area (i.e. earthquakes of magnitude >3), that is perceived to be associated with hydraulic fracture stimulation of the Duvernay. This has been a cause of media coverage lately. We attempt to integrate our results with the induced seismicity data available in the public domain, and have obtained reasonably convincing results. Presentation Date: Wednesday, October 19, 2016 Start Time: 2:20:00 PM Location: 170/172 Presentation Type: ORAL
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Plate Tectonics > Earthquake (0.72)
- North America > Canada > Saskatchewan > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Northwest Territories > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Manitoba > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- (8 more...)
Abstract The interpretation of discrete stratigraphic features on seismic data is limited by its bandwidth and its signal-to-noise ratio. Unfortunately, well-resolved reflections from the top and base of subtle stratigraphic geologic boundaries occur only for thick features imaged by broadband data. Seismically thin stratigraphic features approaching a quarter-wavelength in thickness give rise to composite, or “tuned,” seismic reflections. Different spectral-decomposition methods provide an effective way of examining the seismic response of stratigraphic geologic features in terms of spectral components and thus help in interpretation. Phase components help with interpretation of the discontinuity features as well as stratigraphic features such as onlap, offlap, and erosional unconformities. Applications of an often overlooked attribute derived during spectral decomposition, called the voice components, can be illustrated in terms of more accurate interpretation of the subsurface features. An “amplitude-friendly” method for spectral balancing enhances the frequency content of the data and preserves the geologic tuning features and amplitudes. Spectral decomposition of seismic data that are spectrally balanced and interpreted in terms of voice components leads to more accurate definition of the features of interest.
Abstract The Late Jurassic–Early Cretaceous Vaca Muerta (VM) Formation in the Neuquén Basin has served as an important source rock for many of the conventional oil and gas fields in Argentina. With the interest in developing and exploiting shale resources in the country, many companies there have undertaken characterization of the VM Formation in terms of the elements of shale plays. Among other characteristics, shale plays can be identified based on the total-organic-carbon (TOC) content; better TOC leads to better production. However, there is no way of measuring it directly using seismic data, and it can be estimated only indirectly. Considering the influence of TOC on compressional and shear velocities and density, geoscientists have attempted to compute it using the linear or nonlinear relationship it might have with P-impedance. Understanding the uncertainty in using such a relationship for characterizing the VM Formation, a different approach has been followed for characterizing it. Because a linear relationship seems to exist between gamma ray (GR) and TOC, in addition to P-impedance, gamma ray is another parameter of interest for characterizing the VM Formation. Using P-impedance and GR volumes, a Bayesian classification approach has been followed to obtain a reservoir model with different facies based on TOC and the associated uncertainty with it. As the first step, different facies were defined, based on the cutoff values for GR and P-impedance computed from well-log data. Then Gaussian ellipses were used to capture the distribution of data in a crossplot of GR versus P-impedance. Next, 2D probability density functions (PDFs) were created from the ellipses for each of the facies. Combining these PDFs with GR and P-impedance volumes, different facies were identified on the 3D volume. Poststack model-based inversion was used to compute the P-impedance volume, and the probabilistic neural-network (PNN) approach was used to compute GR volume. Derived P-impedance and GR volumes correlated nicely at blind wells on the 3D volume, which gave confidence in the characterization of the VM Formation. An overlay of the discontinuity detail in terms of curvature lineaments on the determined TOC content at the level of interest helps in obtaining a more complete picture, which is useful for the planning of horizontal wells.
- South America > Argentina > Patagonia Region (1.00)
- South America > Argentina > Neuquén Province > Neuquén (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.74)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.55)
- South America > Colombia > Huila Department > Neiva Basin > Balcon Field (0.99)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Management > Energy Economics > Unconventional resource economics (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
Summary Stratigraphic interpretation of seismic data requires careful interpretation of the amplitude, phase and frequency so as to gauge the geologic subsurface detail. Sometimes the interpretation of the changes in amplitudes is not easy and the equivalent phase is difficult to comprehend. In such cases seismic attributes are utilized to provide additional information that could aid the interpretation. One of the earliest set of ‘instantaneous’ attributes was based on complex trace analysis, and instantaneous phase has been used for interpretation of stratigraphic features such as pinchouts and discontinuities as well as fault edges. In this study, we demonstrate that the interpretability of seismic data can be enhanced with the use of spectral phase components derived during spectral decomposition. As there are different methods for decomposing seismic data into its component frequencies and phase within the seismic bandwidth, we consider two of the common methods in our analysis here, namely the continuous wavelet transform and the matching pursuit methods. We also show that the principal component analysis of spectral magnitude and phase components yields additional insight into the data. The first principal component ‘churned’ out of the phase components shows clarity in the features of interest and compares favourably with the discontinuity attributes commonly used for the purpose. Introduction The strength of seismic reflections carry subsurface information sensitive to absorption and scattering, propagation through fluids and complex interference patterns from stacked stratigraphy. Quantitative interpretation requires that the seismic amplitudes be as ‘true’ as possible, and are not contaminated with noise or other distortions of the acquisition process. In addition to its reflection strength, seismic events are characterized by their frequency and phase. Thin bed interference often increases the high frequency and decreases the low frequency components of the seismic wavelet. For adjacent reflectors having equal but opposite reflection coefficients, the peak amplitude occurs or "tunes" at the quarter wavelength frequency. This latter thin bed tuning phenomena also gives rise to a 90° change in phase. Linear increases and decreases in impedance that may be associated with upward fining or coarsening also give rise to a 90° phase change, as does the reflection from an interface between two units of equal impedance but a finite change in attenuation, or 1/Q. While changes in reflection strength are easy to see, the recognition of such phase and frequency changes are subtle and more easily overlooked on large 3D seismic data volumes. Seismic attributes quantify such subtle changes.
- North America > United States (0.30)
- North America > Canada (0.30)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)