Patent Application
20140200854
Survey design and modeling is the process of evaluating prior data, if any, so as to optimize (or improve) the acquisition of a fresh seismic survey. For conventional marine seismic acquisition comprising pressure-only data acquisition, the process of converting geological objectives into a realizable, cost-effective survey is reasonably well understood. However, for towed marine multimeasurement seismic acquisition, the process is still being explored.
The computing systems, methods, processing procedures, techniques and workflows disclosed herein are more efficient and/or effective methods for identifying, isolating, transforming, and/or processing various aspects of seismic signals or other data that is collected from a subsurface region or other multi-dimensional space.
In accordance with some embodiments, a method is performed for developing a survey design for seismic acquisition that includes analyzing legacy seismic data; and reconstructing a wavefield based on at least the pressure gradient information.
In accordance with some embodiments, a method is performed for developing a survey design for seismic acquisition that includes analyzing legacy seismic data; and reconstructing a wavefield based on at least in part on the pressure information and the analyzed legacy seismic data.
In some embodiments, an aspect of the invention involves determining wavefield pressure gradient information from the legacy seismic data.
In some embodiments, an aspect of the invention involves processing seismic measurement data.
In some embodiments, an aspect of the invention includes that determining the wavefield pressure gradient information includes selecting one or more from the group consisting of: determining inline wavefield pressure gradient information, determining crossline wavefield pressure gradient information, and vertical wavefield pressure gradient information.
In some embodiments, an aspect of the invention includes that analyzing legacy seismic data includes analyzing either in a pre-stack domain or in a post-stack domain or both.
In some embodiments, an aspect of the invention includes that analyzing in a post-stack domain further comprises analysis of migrated 3D volumes of subsurface regions of interest.
In some embodiments, an aspect of the invention involves processing multimeasurement data when reconstructing the wavefield.
In some embodiments, an aspect of the invention involves evaluating the step of reconstructing the wavefield using seismic attributes and rock properties and using quality control metrics in a domain selected from a group comprising: a common shot gather domain, common offset domain, frequency domain, time domain, wavenumber domain, pre-stack domain, and post-stack domain.
In some embodiments, an aspect of the invention involves repeating the step of reconstructing the wavefield using a range of acquisition geometries.
In some embodiments, an aspect of the invention includes that the legacy seismic data includes data selected from a group consisting of multimeasurement towed streamer marine seismic data, dual-sensor towed streamer marine seismic data, over-under towed streamer marine seismic data, slanted-cable towed streamer marine seismic data, towed streamer seismic data, ocean bottom cable (OBC) seismic data, ocean bottom nodes (OBN) seismic data, land seismic data, data from permanent reservoir monitoring systems, borehole seismic data, and microseismic data.
In accordance with some embodiments, a method is performed for developing a survey design for seismic acquisition that includes performing any one of: deriving or estimating a wavefield velocity function; determining an emergence angle using at least the wavefield velocity function; and determining a first set of parameters associated with wavefield reconstruction.
In some embodiments, an aspect of the invention involves processing seismic measurement data.
In some embodiments, an aspect of the invention involves determining a second set of parameters associated with 3D deghosting.
In some embodiments, an aspect of the invention includes that the wavefield velocity function can be 1D, 2D, 3D or 4D.
In some embodiments, an aspect of the invention involves determining data receiver spacing.
In some embodiments, an aspect of the invention involves determining optimal streamer tow depth in the case of towed streamer marine seismic data.
In some embodiments, an aspect of the invention involves determining a streamer tow depth in the case of towed streamer marine seismic data.
In some embodiments, an aspect of the invention includes that determining a set of parameters further comprises determining interaction of aliasing and ghost notch frequencies with respect to one or more criteria selected from the group consisting of time, offset, and receiver spacing.
In some embodiments, an aspect of the invention includes that determining a set of parameters further comprises determining interaction of aliasing and ghost notch frequencies with time, offset, and receiver spacing.
In some embodiments, an aspect of the invention involves processing any one of a set consisting of: multi-measurement data, dual-sensor data and single sensor data.
In some embodiments, an aspect of the invention involves analyzing legacy seismic data.
In some embodiments, an aspect of the invention involves using one or more quality control metrics from a domain selected from the group consisting of frequency domain, time domain, wavenumber domain, pre-stack domain and post-stack domain.
In some embodiments, an aspect of the invention involves determining a range of acquisition geometries for the survey design.
In some embodiments, an aspect of the invention includes that seismic data used in the method is selected from the group consisting of multimeasurement towed streamer marine seismic data, dual-sensor towed streamer marine seismic data, over-under towed streamer marine seismic data, slanted-cable towed streamer marine seismic data, towed streamer seismic data, ocean bottom cable (OBC) seismic data, ocean bottom nodes (OBN) seismic data, land seismic data, data from permanent reservoir monitoring systems, borehole seismic data, and microseismic data.
In accordance with some embodiments, a method is performed for developing a survey design for seismic acquisition that includes determining geologic property models associated with geologic regions of interest; determining a synthetic set of associated seismic data; and reconstructing a wavefield using at least the synthetic set of associated seismic data.
In some embodiments, an aspect of the invention involves processing seismic measurement data.
In some embodiments, an aspect of the invention includes that determining the synthetic set includes performing one or more techniques selected from the group consisting of finite-difference modeling, finite element modeling, spectral element methods, tomography and ray tracing.
In some embodiments, an aspect of the invention involves determining one or more models selected from the group consisting of velocity models, density models, attenuation models, anisotropy models, and wave-heights models.
In some embodiments, an aspect of the invention involves performing 3D deghosting.
In some embodiments, an aspect of the invention involves using a noise model on at least a subset of acceleration components and pressure components.
In some embodiments, an aspect of the invention involves analyzing legacy seismic data.
In some embodiments, an aspect of the invention involves performing ray tracing.
In some embodiments, an aspect of the invention involves evaluating the step of reconstructing the wavefield using seismic attributes and rock properties; and using one or more quality control metrics from a domain selected from the group consisting of a common shot gather domain, common offset domain, migration domain and post migration domain, frequency domain, time domain, wavenumber domain.
In some embodiments, an aspect of the invention involves repeating the step of reconstructing the wavefield using a range of acquisition geometries.
In some embodiments, an aspect of the invention involves using a domain selected from a group comprising a common shot gather domain, common offset domain, migration domain and post migration domain.
In some embodiments, an aspect of the invention includes that the seismic data includes data selected from the group consisting of multimeasurement towed streamer marine seismic data, dual-sensor towed streamer marine seismic data, over-under towed streamer marine seismic data, slanted-cable towed streamer marine seismic data, towed streamer seismic data, ocean bottom cable (OBC) seismic data, ocean bottom nodes (OBN) seismic data, land seismic data, data from permanent reservoir monitoring systems, borehole seismic data, and microseismic data.
In some embodiments, a computing system is provided that comprises at least one processor, at least one memory, and one or more programs stored in the at least one memory, wherein the programs comprise instructions, which when executed by the at least one processor, are configured to perform any method disclosed herein.
In some embodiments, a computer readable storage medium is provided, which has stored therein one or more programs, the one or more programs comprising instructions, which when executed by a processor, cause the processor to perform any method disclosed herein.
In some embodiments, a computing system is provided that comprises at least one processor, at least one memory, and one or more programs stored in the at least one memory; and means for performing any method disclosed herein.
In some embodiments, an information processing apparatus for use in a computing system is provided, and that includes means for performing any method disclosed herein.
These systems, methods, processing procedures, techniques and workflows increase effectiveness and efficiency. Such systems, methods, processing procedures, techniques and workflows may complement or replace conventional methods for identifying, isolating, transforming and/or processing various aspects of seismic signals or other data that is collected from a subsurface region or other multi-dimensional space.
Reference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures. In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention. However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details. In other instances, well-known methods, procedures, components, circuits and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.
It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms. These terms are only used to distinguish one element from another. For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the invention. The first object or step, and the second object or step, are both objects or steps, respectively, but they are not to be considered the same object or step.
The terminology used in the description of the invention herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention. As used in the description of the invention and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will also be understood that the term “and/or” as used herein refers to and encompasses any and all possible combinations of one or more of the associated listed items. It will be further understood that the terms “includes,” “including,” “comprises,” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.
As used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.
Those with skill in the art will appreciate that while some terms in this disclosure may refer to absolutes, e.g., all of the components of a wavefield, all source receiver traces, each of a plurality of objects, etc., the methods and techniques disclosed herein may also be performed on fewer than all of a given thing, e.g., performed on one or more components and/or performed on one or more source receiver traces. Accordingly, in instances in the disclosure where an absolute is used, the disclosure may also be interpreted to be referring to a subset.
According to certain embodiments, the disclosed methods provide a framework of investigation, including modular workflows to optimize (or improve) the acquisition geometry and its efficiency without compromising on the survey objectives. In some embodiments, the disclosed methods and computing systems include a focus on 3D deghosting and wavefield reconstruction methods enabled by multicomponent seismic information.
According to certain embodiments, survey design and modeling (SD&M) is the process of evaluating prior data, if any, so as to optimize (or improve) the acquisition of a fresh seismic survey. For example, certain embodiments of the modular workflows are applicable to multicomponent seismic seabed data, and multicomponent seismic land data, in addition to the multicomponent seismic marine data, as described in greater detail herein. Further, certain embodiments of the modular workflows may be used with any seismic data such as seismic data associated with a single sensor, as a non-limiting example.
According to certain embodiments, wavefield reconstruction denotes any combination of interpolation and/or deghosting, using one, two or more wavefield components (recordings).
For conventional marine seismic acquisition comprising pressure-only data acquisition, the process of converting geological objectives into a realizable, cost-effective survey is reasonably well understood. However, towed marine multicomponent seismic acquisition requires a different approach from that which is appropriate for hydrophone-only acquisition.
According to certain embodiments, bandwidth enhancement between receiver positions overcoming higher order aliasing is a core value proposition of SD&M systems. It is the optimization (or improvement) of wavefield reconstruction and / or deghosting for SD&M using different levels of sophistication. In other words, designing a survey which takes advantage of wavefield reconstruction and/or deghosting to optimize the survey objectives represents at least some of the novel aspects discussed herein.
Certain embodiments disclosed herein provide a novel framework of investigation, including three modular workflows and appropriate quality control (QC) steps to evaluate reconstruction performance and to optimize (or improve) the acquisition geometry and its efficiency without compromising on the survey objectives. One part of such a framework is building the seismic model (e.g., building the physical property models of the subsurface regions of interest). The seismic model can range from simple to complex depending on the objectives of the survey, and the available resources. In some circumstances, when using a more complex and accurate seismic model, the processing can achieve a higher quality wavefield reconstruction and/or deghosting.
Wavefield reconstruction between individual receiver positions is used to overcome spatial aliasing and to improve temporal bandwidth for multicomponent seismic data, according to certain embodiments.
The performance of the wavefield reconstruction and deghosting based on multicomponent recordings is impacted by many factors such as the level of noise on the individual components, the streamer spacing, the streamer tow depth, the amplitude, frequency content and crossline dip of seismic events that, in turn, are affected by the subsurface geology. These factors impact the quality of wavefield reconstruction and deghosting as a function of interpolation distance. Therefore, in some conditions, it can be desirable to optimize (or improve) the acquisition design to ensure that the quality of the reconstructed wavefields is appropriate for the survey objectives.
A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.
The storage media 106 may be implemented as one or more computer-readable or machine-readable storage media. While in the example embodiment
It should be appreciated that computer system 101A is only one example of a computing system, and that computer system 101A may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of
It should also be appreciated that while no user input/output peripherals are illustrated with respect to computer systems 101A, 101B, 101C, and 101D, many embodiments of computing system 100 include computing systems with keyboards, mice, touch screens, displays, etc. Some computing systems in use in computing system 100 may be desktop workstations, laptops, tablet computers, smartphones, server computers, etc.
Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices. These modules, combinations of these modules, and/or their combination with general hardware are all included within the scope of protection of the invention.
Attention is now directed to methods, techniques and workflows for processing and/or generating survey design and modeling that are in accordance with certain embodiments. Some operations in the processing procedures, methods, techniques and workflows disclosed herein may be combined and/or the order of some operations may be changed. It is important to recognize that in the geosciences, various geologic interpretations, sets of assumptions, and/or domain models such as velocity models, may be refined in an iterative fashion; this concept is applicable to the procedures, methods, techniques and workflows as discussed herein. This iterative refinement can include use of feedback loops executed on an algorithmic basis, such as at a computing device (e.g., computing system 100,
A multimeasurement (multicomponent) towed seismic cable acquires pressure from a hydrophone and multiple orthogonally aligned components of particle acceleration. A non-limiting example of such a cable is described in, “On the use of multicomponent streamer recordings for reconstruction of pressure wavefields in the crossline direction” (Robertsson et al. 2008: Geophysics, 73(5), A45-A49), herein referred to as “Robertsson et al. 2008,” and which is incorporated by reference in its entirety. From acceleration, {dot over (V)}, the gradient of pressure, ∇P, can be derived using the relation: ∇P=−ρ{dot over (V)}, where the dot denotes time derivative. Two axially-orthogonal components are needed to span the space perpendicular to the streamer axis, but only the vertical component, Vz, is needed to perform up/down wavefield separation. An equivalent measurement to Vx can be obtained directly from the in-line gradient of pressure, P. One application for Vy lies in its potential to overcome higher order aliasing in the cross-line direction with respect to pressure-only data. Non-limiting examples of such an application for Vy are described in, “A discussion of sampling theorems. Proceedings of the Institute of Radio Engineers Linden 1959: 47, 1219-1226), herein referred to as “Linden 1959”, and which is incorporated by reference in its entirety; “Crossline wavefield reconstruction from multicomponent streamer data: Part 2—Joint interpolation and 3D up/down separation by generalized matching pursuit” (Özbek et al., 2010: Geophysics, 75, WB69-WB85), herein referred to as “Özbek et al., 2010”, and which is incorporated by reference in its entirety; Robertsson et al. 2008.
The potential to double the Nyquist wavenumber has an immediate benefit in conventional wavefield interpolation but methods such as multi-channel interpolation by matching pursuit (see “Crossline wavefield reconstruction from multicomponent streamer data, Part 1: Interpolation by matching pursuit using pressure and its crossline gradient.” Geophysics, 75, WB53-WB67, herein referred to as “MIMAP” or “Vassallo et al., 2010,” and which is incorporated by reference in its entirety) can reconstruct the total pressure wavefield beyond the Nyquist wavenumber by matching both pressure and its cross-line gradient, Vy. Joint interpolation and deghosting, whereby the upgoing pressure wavefield is estimated at an arbitrary point within an aperture of multimeasurement streamers, may be achieved through a generalized matching pursuit algorithm (GMP) that simultaneously models the acquired data P, Vz and Vy (Özbek et al., 2010).
Studies on both synthetic and real seismic data have shown in a qualitative and quantitative manner that these methods are robust (for example, “The fidelity of 3D wavefield reconstruction from a four-component marine streamer and its implications for time-lapse seismic measurements”, Eggenberger et al., 2012: 82nd Meeting Society of Exploration Geophysicists, Expanded Abstract, doi: 10.1190/segam2012-0908.1, herein referred to as “Eggenberger et al., 2012”, and which is incorporated by reference in its entirety); Özbek et al., 2010). However, the performance of such methods in the presence of noise depends, amongst other things, on the streamer spacing, the streamer tow depth, and the frequency content and crossline dip of seismic events, which in turn are affected by the subsurface geology. This translates into a dependency on interpolation distance and, therefore, it is desirable to optimize (or improve) the acquisition geometry before the actual survey, based on survey objectives. Such work is not well understood for acquisition using multimeasurement streamers. A framework of survey evaluation and design to address this challenge is described herein. Such work is based on prior information such as legacy seismic data and models of the physical properties of the subsurface. Such properties of the subsurface then can be utilized in finite difference modeling to mimic the earth response for a range of geometries, to assess the reconstruction performance and to streamline acquisition geometry for the needs of the survey.
The description herein describes towed multimeasurement seismic in detail.
Certain embodiments as described herein disclose a framework of survey evaluation and design that includes three workflows to address the challenge of SD&M where the centerpiece of investigation deals with wavefield reconstruction of any kind with the aim to overcome (or at least mitigate) bandwidth constraints. Such SD&M work is based on prior information such as legacy seismic data and models of the physical properties of the subsurface. Property models can be used in finite difference modeling to mimic the earth response for a range of geometries, to assess the reconstruction performance and to streamline acquisition geometry for the needs of the survey which can, for instance, comprise illumination, time-lapse signal, efficiency or a combination thereof. It is also possible to evaluate the uplift that wavefield reconstruction brings to a given acquisition scenario in a vertically integrated manner. For example, full waveform modeling can generate individual shots, or 2D and 3D surveys, for processing through migration, waveform inversion and rock property estimation, evaluating the end products and testing appropriate processing flows in advance of the actual acquisition.
In
According to certain embodiments, the findings from the legacy seismic data analysis workflow (201) can be input into the seismic ray-tracing workflow (202). At step 206, findings from the legacy seismic data analysis workflow (201) can be used to estimate the velocity function, which, together with the expected signal bandwidth and time-dip can, in turn, be used to determine optimal (or suitable) spacing of the streamers (cable spacing) at step 207, and determine optimal (or suitable) tow depth at step 208. According to certain embodiments, the velocity function can be of varied complexity, e.g., 1D, 2D, 3D or 4D.
According to certain embodiments, the findings from the seismic ray-tracing workflow (202) can be input into the seismic modeling workflow (203). At step 209, physical property models of the subsurface are obtained. At step 210, a synthetic data model is generated using a range of realistic additive noise fields. At step 211, the wavefield is reconstructed on the shot gathers. At step 212, reconstruction errors are evaluated. According to certain embodiments, the wavefield reconstruction and error evaluation loop can be repeated on the modeled data for a range of acquisition geometries (step 213). According to certain embodiments, wavefield reconstruction can take into account seismic attributes such as rock porosity. At step 214, a decision can be made on the optimal (or suitable, or acceptable) acquisition geometry.
The steps shown are merely illustrative and do not necessarily represent the full breadth of survey design and modeling involved for multicomponent data. For instance the modeling, wavefield reconstruction and evaluation can comprise different levels of complexity, which can extend through imaging into the post-stack domain for analysis. For example, the level of complexity may depend on the objectives of the survey project, the available resources, the risk tolerance and/or the amount of time available for the survey project.
Those with skill in the art, however, will appreciate that the methods and computing systems disclosed herein may also be employed with dual-sensor towed streamer marine seismic data, over-under towed streamer marine seismic data, slanted-cable towed streamer marine seismic data, towed streamer seismic data, land seismic data, ocean bottom cable seismic (OBC), ocean bottom nodes (OBN), and semi-permanent or permanent reservoir monitoring systems where it is sought to overcome the sparsity of spatial sampling into one or more dimensions, using multichannel wavefield reconstruction, deghosting, and/or demultiple techniques.
Furthermore, the example framework in
Those with skill in the art will also appreciate that the framework discussed herein may be supplemented with appropriate quality control measures to determine the quality of the reconstruction, demultiple processing, and/or deghosting techniques as applied. A non-exclusive list of such measures can contain 4D metrics like Normalized Root Mean Square (NRMS) and predictability (see for example, “Seismic repeatability, normalized RMS, and predictability,” The Leading Edge, Kragh and Christie, 2002: 21(7), pp. 640-647), also in a frequency dependent mode, and f-k plots in 2D and 3D. Quality control metrics can be performed in a variety of domains such as frequency domain, time domain, wavenumber domain, pre-stack domain and post-stack domain.
Additionally, those with skill in the art will appreciate that many forms of input models may be used for seismic modeling successfully with the example framework, methods, computing systems, and techniques disclosed herein, including the following non-limiting examples, velocity models, anisotropy models (utilizing delta and epsilon), Q-models relating to 3D attenuation, etc. In some embodiments, a plurality of input models may be used for seismic modeling to increase accuracy of the results.
Often, legacy seismic data are available in survey areas of interest. For the purpose of wavefield reconstruction, these data can be analyzed in two complementary domains: pre-stack and post-stack. The post-stack analysis deals with final migrated 3D volumes of the subsurface where individual regions of the subsurface—the reservoir, but also the over- and underburden—are investigated in terms of geological features.
For purposes of illustration,
The legacy seismic data analysis can guide both waveform modeling and ray tracing. The latter can provide a quick look at cable spacing and the bandwidth over which multi-channel reconstruction may be expected to provide uplift, and identify the interaction of aliasing and ghost notch frequencies with time, offset, and cable spacing, as shown in
In some embodiments, one parameter provided by the ray-tracing is the 3D emergence angle of the wavefield. With the known medium velocity, this angle can be used to determine the wavenumber vector which controls the accelerometer response. This can narrow the range of effective cable spacing and can enable initial estimates of signal-to-noise ratios, especially for accelerometers. More sophisticated 2D or 3D ray tracing can explore a specific structure, if the velocity field is known. Furthermore, in some embodiments, a ray tracer with incorporated reconstruction and deghosting algorithm can directly produce targeted quality metrics, and in some embodiments, in 4D.
Legacy seismic data can guide waveform modeling since 3D velocity models are often available which approximate the main geological features. Physical property models of the subsurface are also generated prior to a seismic survey by combining seismic, well-log and geological information. The third workflow (203 of
In some embodiments, once shot locations, appropriate for the geological challenge, are selected, they are modeled using an initial acquisition geometry and a range of realistic additive noise fields. In some embodiments, the trial wavefield reconstructions cover single- and multi-channel algorithms to evaluate the uplift achieved through the additional acceleration measurements. In some embodiments, reconstruction performance may be evaluated using 4D metrics against undecimated reference synthetics in conjunction with spectral analysis and frequency-wavenumber plots in both 2D and 3D. This loop may then be repeated on the modeled data for a range of acquisition geometries, changing cable separation to optimize (or improve) reconstruction performance and operational efficiency while addressing the survey objectives.
As those with skill in the art will appreciate, the seismic modeling may be performed in the common shot gather domain, the common offset domain, the migration domain, post migration domain or any domain suitable to exercise the multichannel wavefield reconstruction, demultiple processing, and/or deghosting algorithms.
Survey evaluation and design for a towed marine multimeasurement survey requires a different approach than for hydrophone-only acquisition, focusing on crossline wavefield reconstruction between streamer positions. To optimize (or increase) acquisition efficiency without compromising the survey objectives, the described framework is based on a combination of one or more of three pillars: legacy data analysis, ray tracing to explore geometry impact, and full wavefield modeling to evaluate reconstruction performance. Production-scale finite difference modeling provides a powerful workflow to optimize (or improve) wavefield reconstruction parameters and thus guide the acquisition effort.
According to certain embodiments, multimeasurement streamer processing includes performing legacy seismic data processing on the seismic data corresponding to a region of interest.
The steps in the processing methods described above may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices. These modules, combinations of these modules, and/or their combination with general hardware are all included within the scope of protection of the invention.
While the discussion of related art in this disclosure may or may not include some prior art references, applicant neither concedes nor acquiesces in the position that any given reference is prior art or analogous prior art.
The foregoing description, for purpose of explanation, has been described with reference to specific embodiments. However, the illustrative discussions above are not intended to be exhaustive or to limit the invention to the precise forms disclosed. Many modifications and variations are possible in view of the above teachings. The embodiments were chosen and described in order to best explain the principles of the invention and its practical applications, to thereby enable others skilled in the art to best utilize the invention and various embodiments with various modifications as are suited to the particular use contemplated.
This application claims the benefit of U.S. Provisional Patent Application Ser. No. 61/752,638 filed Jan. 15, 2013, entitled, “Methods and Computing Systems for Survey Design and Modeling Workflow for Towed Multimeasurement Seismic Streamer Data,” which is hereby incorporated by reference in its entirety.
| Number | Date | Country | |
|---|---|---|---|
| 61752638 | Jan 2013 | US |
