Patents by Inventor Tetyana Vdovina
Tetyana Vdovina has filed for patents to protect the following inventions. This listing includes patent applications that are pending as well as patents that have already been granted by the United States Patent and Trademark Office (USPTO).
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Patent number: 10670750Abstract: A multi-stage FWI workflow uses multiple-contaminated FWI models to predict surface-related multiples. A method embodying the present technological advancement, can include: using data with free surface multiples as input into FWI; generating a subsurface model by performing FWI with the free-surface boundary condition imposed on top of the subsurface model; using inverted model from FWI to predict multiples; removing predicted multiples from the measured data; using the multiple-free data as input into FWI with absorbing boundary conditions imposed on top of the subsurface model; and preparing a multiple free data set for use in conventional seismic data processing.Type: GrantFiled: October 26, 2015Date of Patent: June 2, 2020Assignee: ExxonMobil Upstream Research CompanyInventors: Tetyana Vdovina, Reeshidev Bansal, Anatoly Baumstein, Yaxun Tang, Di Yang
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Patent number: 10520618Abstract: A method for exploring for hydrocarbons, including: simulating a seismic waveform, using a computer, wherein computations are performed on a computational grid representing a subsurface region, said computational grid using perfectly matched layer (PML) boundary conditions that use an energy dissipation operator to minimize non-physical wave reflections at grid boundaries; wherein, in the simulation, the PML boundary conditions are defined to reduce computational instabilities at a boundary by steps including, representing direction of energy propagation by a Poynting vector, and dissipating energy, with the dissipation operator, in a direction of energy propagation instead of in a phase velocity direction; and using the simulated waveform in performing full waveform inversion or reverse time migration of seismic data, and using a physical property model from the inversion or a subsurface image from the migration to explore for hydrocarbons.Type: GrantFiled: October 20, 2015Date of Patent: December 31, 2019Assignee: ExxohnMobil Upstream Research CompanyInventors: Tetyana Vdovina, Valeriy Brytik, John E. Anderson, Thomas A. Dickens, William Curry, Carey M. Marcinkovich
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Patent number: 10459096Abstract: A method for iteratively inverting seismic data to jointly infer a model for at least P-wave velocity and attenuation parameters of the subsurface, the method including: jointly inverting the P-wave velocity and attenuation parameters with an iterative visco-acoustic full wavefield inversion process, wherein the iterative visco-acoustic full wavefield inversion process includes computing a gradient of an objective function, the objective function measuring a misfit between all or part of the seismic data and corresponding model-simulated seismic data; for each of the P-wave velocity and attenuation parameters, computing a search direction in model space from the gradient; determining line search step sizes ? and ? for the search directions for the P-wave velocity and attenuation parameters, respectively, wherein a ratio of the step sizes is a function of the P-wave velocity parameter; and using the step sizes ? and ? and the search directions for each of the P-wave velocity and attenuation parameters, computiType: GrantFiled: June 6, 2017Date of Patent: October 29, 2019Assignee: ExxonMobil Upstream Research CompanyInventors: Sirui Tan, Yaxun Tang, Anatoly I. Baumstein, Gboyega Ayeni, Tetyana Vdovina, Thomas A. Dickens
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Patent number: 10338244Abstract: A method, including performing, with a computer, up/down separation of geophysical data, which produces an approximate up-going wavefield and an approximate down-going wavefield; creating an areal source based at least in part on the down-going wavefield; and performing, with a computer, a full wavefield inversion process with the areal source, and an objective function measuring a misfit between modeled up-going wavefields and recorded up-going wavefields, wherein the full wavefield inversion process generates a final subsurface physical property model.Type: GrantFiled: April 3, 2017Date of Patent: July 2, 2019Assignee: ExxonMobil Upstream Research CompanyInventors: Anatoly I Baumstein, Di Yang, Tetyana Vdovina, Yaxun Tang
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Patent number: 10185046Abstract: Method for correcting seismic simulations, RTM, and FWI for temporal dispersion due to temporal finite difference methods in which time derivatives are approximated to a specified order of approximation. Computer-simulated seismic data (51) are transformed from time domain to frequency domain (52), and then resampled using a mapping relationship that maps, in the frequency domain, to a frequency at which the time derivative exhibits no temporal dispersion (53), or to a frequency at which the time derivative exhibits a specified different order of temporal dispersion. Alternatively, measured seismic data from a field survey (61) may have temporal dispersion of a given order introduced, by a similar technique, to match the order of approximation used to generate simulated data which are to be compared to the measured data.Type: GrantFiled: March 26, 2015Date of Patent: January 22, 2019Assignee: ExxonMobil Upstream Research CompanyInventors: John E. Anderson, Anatoly Baumstein, Carey Marcinkovich, Tetyana Vdovina, Valeriy Brytik
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Publication number: 20180017690Abstract: A method for iteratively inverting seismic data to jointly infer a model for at least P-wave velocity and attenuation parameters of the subsurface, the method including: jointly inverting the P-wave velocity and attenuation parameters with an iterative visco-acoustic full wavefield inversion process, wherein the iterative visco-acoustic full wavefield inversion process includes computing a gradient of an objective function, the objective function measuring a misfit between all or part of the seismic data and corresponding model-simulated seismic data; for each of the P-wave velocity and attenuation parameters, computing a search direction in model space from the gradient; determining line search step sizes ? and ? for the search directions for the P-wave velocity and attenuation parameters, respectively, wherein a ratio of the step sizes is a function of the P-wave velocity parameter; and using the step sizes ? and ? and the search directions for each of the P-wave velocity and attenuation parameters, computiType: ApplicationFiled: June 6, 2017Publication date: January 18, 2018Inventors: Sirui Tan, Yaxun Tang, Anatoly I. Baumstein, Gboyega Ayeni, Tetyana Vdovina, Thomas A. Dickens
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Publication number: 20170307770Abstract: A method, including performing, with a computer, up/down separation of geophysical data, which produces an approximate up-going wavefield and an approximate down-going wavefield; creating an areal source based at least in part on the down-going wavefield; and performing, with a computer, a full wavefield inversion process with the areal source, and an objective function measuring a misfit between modeled up-going wavefields and recorded up-going wavefields, wherein the full wavefield inversion process generates a final subsurface physical property model.Type: ApplicationFiled: April 3, 2017Publication date: October 26, 2017Inventors: Anatoly I. BAUMSTEIN, Di Yang, Tetyana Vdovina, Yaxun Tang
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Publication number: 20160238722Abstract: A multi-stage FWI workflow uses multiple-contaminated FWI models to predict surface-related multiples. A method embodying the present technological advancement, can include: using data with free surface multiples as input into FWI; generating a subsurface model by performing FWI with the free-surface boundary condition imposed on top of the subsurface model; using inverted model from FWI to predict multiples; removing predicted multiples from the measured data; using the multiple-free data as input into FWI with absorbing boundary conditions imposed on top of the subsurface model; and preparing a multiple free data set for use in conventional seismic data processing.Type: ApplicationFiled: October 26, 2015Publication date: August 18, 2016Inventors: Tetyana VDOVINA, Reeshidev Bansal, Anatoly Baumstein, Yaxun Tang, Di Yang
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Publication number: 20160223697Abstract: A method for exploring for hydrocarbons, including: simulating a seismic waveform, using a computer, wherein computations are performed on a computational grid representing a subsurface region, said computational grid using perfectly matched layer (PML) boundary conditions that use an energy dissipation operator to minimize non-physical wave reflections at grid boundaries; wherein, in the simulation, the PML boundary conditions are defined to reduce computational instabilities at a boundary by steps including, representing direction of energy propagation by a Poynting vector, and dissipating energy, with the dissipation operator, in a direction of energy propagation instead of in a phase velocity direction; and using the simulated waveform in performing full waveform inversion or reverse time migration of seismic data, and using a physical property model from the inversion or a subsurface image from the migration to explore for hydrocarbons.Type: ApplicationFiled: October 20, 2015Publication date: August 4, 2016Inventors: Tetyana Vdovina, Valeriy Brytik, John E. Anderson, Thomas A. Dickens, William Curry, Carey M. Marcinkovich
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Publication number: 20160061974Abstract: Method for performing a full wavefield inversion (FWI) without simulating free-surface multiple reflections. The free-surface multiples are removed from the field gathers of seismic data, which are then used to generate a subsurface velocity model by FWI. In the FWI, the field monopole sources and receivers are replaced with dipole (actual and mirror image) sources and receivers (21) when model-simulating (23) synthetic survey data. Also, direct arrivals at the mirror receiver locations are preferably simulated (25) with the dipole sources for each shot location and added (26) to the synthetic survey data (24) for that shot location, resulting in corrected synthetic survey data (27), which is used in the FWI to generate residuals. A model update may be computed by back-propagating the residuals by injecting them at both mirror and actual receiver locations.Type: ApplicationFiled: July 16, 2015Publication date: March 3, 2016Inventors: Reeshidev Bansal, Anatoly Baumstein, Tetyana Vdovina, Dongxing Wang, Hongchuan Sun
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Publication number: 20150355356Abstract: Method for correcting seismic simulations, RTM, and FWI for temporal dispersion due to temporal finite difference methods in which time derivatives are approximated to a specified order of approximation. Computer-simulated seismic data (51) are transformed from time domain to frequency domain (52), and then resampled using a mapping relationship that maps, in the frequency domain, to a frequency at which the time derivative exhibits no temporal dispersion (53), or to a frequency at which the time derivative exhibits a specified different order of temporal dispersion. Alternatively, measured seismic data from a field survey (61) may have temporal dispersion of a given order introduced, by a similar technique, to match the order of approximation used to generate simulated data which are to be compared to the measured data.Type: ApplicationFiled: March 26, 2015Publication date: December 10, 2015Inventors: John E. Anderson, Anatoly Baumstein, Carey Marcinkovich, Tetyana Vdovina, Valeriy Brytik