Patents by Inventor Christine E. Krohn
Christine E. Krohn 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: 10386511Abstract: Method for selecting an acquisition geometry for a seismic survey based on ability to resolve an a priori velocity model. Two or more candidate acquisition geometries are selected (301, 302), differing in areal coverage and cost to perform. Then compute a synthetic seismic dataset for each geometry using a detailed geometrical reference model of the subsurface (301). Invert the synthetic seismic datasets preferably using simultaneous source FWI, and preferably with Volume of Investigation constraints, to determine model updates (303, 304). Quantitatively assess the value of the additional traces in a fuller dataset relative to a subset (306), using one or more statistics based on the accuracy of the updated models, such as improved match to the reference model, better fit of seismic data, or rate of change in improvement with iterations. Inversions may be cascaded for further efficiency (314).Type: GrantFiled: July 13, 2015Date of Patent: August 20, 2019Assignee: ExxonMobil Upstream Research CompanyInventors: Partha S. Routh, Nathan Downey, Christine E. Krohn
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Patent number: 9772413Abstract: Method for acquiring, at reduced acquisition cost, seismic data using simultaneous, field-encoded sources in the field (702), and then constructing pseudo source-records (703) that better meet the requirements for using additional simultaneous computer-encoded sourcing for computer simulations or forward modeling (706) as part of (707) iterative FWI (Full Wavefield Inversion) or RTM (Reverse Time Migration), with additional reduction in computational costs. By better meeting the requirements of simultaneous sourcing for FWI or RTM (701), artifacts and crosstalk are reduced in the output. The method can be used for marine streamer acquisition and other non-fixed spread geometries to acquire both positive and negative offsets and to mitigate the “missing data” problem for simultaneous-source FWI. It can also be used for land data to overcome issues with moving spreads and long continuous records.Type: GrantFiled: July 11, 2014Date of Patent: September 26, 2017Assignee: ExxonMobil Upstream Research CompanyInventors: Christine E. Krohn, Partha S. Routh
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Patent number: 9442204Abstract: Method for inverting seismic data to obtain reflection properties by estimating or measuring (301) the source signature for the seismic data, then inverting (302) simultaneously for subsurface formation properties or reflection properties and for the amplitude attenuation and velocity dispersion effects integrated over the raypath from the source to the reflectors and to the receiver.Type: GrantFiled: July 12, 2013Date of Patent: September 13, 2016Assignee: ExxonMobil Upstream Research CompanyInventor: Christine E. Krohn
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Patent number: 9405026Abstract: Method for estimating fluid heterogeneity in a subsurface region from seismic wave attenuation or velocity dispersion that is either measured or extracted from geophysical data (210). A rock physics model in the form of a mathematical relationship is selected that relates attenuation or velocity to frequency and to physical properties that are related to fluid heterogeneity (220). The model, or asymptotes (230) representing the model's behavior at frequency extremes, is inverted (240) and that relationship is used to obtain (250) one or more of the physical properties related to fluid heterogeneity, such as characteristic length scale for fluid saturation heterogeneities (270) and relative volume fractions of the fluids saturating the pore space (280).Type: GrantFiled: September 11, 2012Date of Patent: August 2, 2016Assignee: ExxonMobil Upstream Research CompanyInventors: Julianna J. Toms, Christine E. Krohn, Enru Liu
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Patent number: 9348050Abstract: A seismic data processing method for predicting and removing unwanted near-surface noise, e.g. refracted waves and surface waves, from composite seismograms acquired with multiple, encoded seismic sources in which the time records from the different sources overlap or interfere. Surface-consistent properties are determined (403) for the near-surface noise and used to predict the noise waveforms (404) for the composite simultaneous-source seismograms, and the waveforms are then subtracted or adaptively subtracted (406) from the seismograms.Type: GrantFiled: May 3, 2013Date of Patent: May 24, 2016Assignee: ExxonMobil Upstream Research CompanyInventor: Christine E. Krohn
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Publication number: 20160097870Abstract: Method for selecting an acquisition geometry for a seismic survey based on ability to resolve an a priori velocity model. Two or more candidate acquisition geometries are selected (301, 302), differing in areal coverage and cost to perform. Then compute a synthetic seismic dataset for each geometry using a detailed geometrical reference model of the subsurface (301). Invert the synthetic seismic datasets preferably using simultaneous source FWI, and preferably with Volume of Investigation constraints, to determine model updates (303, 304). Quantitatively assess the value of the additional traces in a fuller dataset relative to a subset (306), using one or more statistics based on the accuracy of the updated models, such as improved match to the reference model, better fit of seismic data, or rate of change in improvement with iterations. Inversions may be cascaded for further efficiency (314).Type: ApplicationFiled: July 13, 2015Publication date: April 7, 2016Inventors: Partha S. Routh, Nathan Downey, Christine E. Krohn
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Publication number: 20150057938Abstract: Method for acquiring, at reduced acquisition cost, seismic data using simultaneous, field-encoded sources in the field (702), and then constructing pseudo source-records (703) that better meet the requirements for using additional simultaneous computer-encoded sourcing for computer simulations or forward modeling (706) as part of (707) iterative FWI (Full Wavefield Inversion) or RTM (Reverse Time Migration), with additional reduction in computational costs. By better meeting the requirements of simultaneous sourcing for FWI or RTM (701), artifacts and crosstalk are reduced in the output. The method can be used for marine streamer acquisition and other non-fixed spread geometries to acquire both positive and negative offsets and to mitigate the “missing data” problem for simultaneous-source FWI. It can also be used for land data to overcome issues with moving spreads and long continuous records.Type: ApplicationFiled: July 11, 2014Publication date: February 26, 2015Inventors: Christine E. Krohn, Partha S. Routh
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Patent number: 8892410Abstract: A method for transforming seismic surface waves into depth profiles of dynamic properties of the soil such as the soil shear modulus or wave velocity or wave attenuation. The invention uses seismic data recorded preferably with a plurality of sources and receivers with a two-stage inversion approach. First, variations in surface-wave waveforms are decomposed (303) into surface-consistent transfer functions preferably for each source, each receiver, and each small region (301) of the surface. Then the transfer functions for each region are inverted (308) to determine soil properties or near-surface properties (such as the shear modulus) as a function of depth. The method can solve for the complex multi-mode nature of the surface waves for a media with both vertical and lateral changes in properties. Errors and limits in resolution for traditional methods from misidentification of ground roll modes or from assuming laterally uniform soil properties are avoided.Type: GrantFiled: June 19, 2009Date of Patent: November 18, 2014Assignee: ExxonMobil Upstream Research CompanyInventor: Christine E. Krohn
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Publication number: 20140039799Abstract: Method for inverting seismic data to obtain reflection properties by estimating or measuring (301) the source signature for the seismic data, then inverting (302) simultaneously for subsurface formation properties or reflection properties and for the amplitude attenuation and velocity dispersion effects integrated over the raypath from the source to the reflectors and to the receiver.Type: ApplicationFiled: July 12, 2013Publication date: February 6, 2014Inventor: Christine E. Krohn
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Publication number: 20130315033Abstract: A seismic data processing method for predicting and removing unwanted near-surface noise, e.g. refracted waves and surface waves, from composite seismograms acquired with multiple, encoded seismic sources in which the time records from the different sources overlap or interfere. Surface-consistent properties are determined (403) for the near-surface noise and used to predict the noise waveforms (404) for the composite simultaneous-source seismograms, and the waveforms are then subtracted or adaptively subtracted (406) from the seismograms.Type: ApplicationFiled: May 3, 2013Publication date: November 28, 2013Inventor: Christine E. KROHN
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Patent number: 8553497Abstract: The invention is a method to predict surface-wave waveforms (306) and subtract them (307) from seismic data. Prediction is done by estimating a set of surface-consistent components (transfer functions in the frequency domain or impulse responses in time domain) that best represent changes in the waveforms for propagation along the surface from source to receiver (303). The prediction uses a mathematical expression, or model, of the earth's filtering effects, both amplitude and phase, as a function of frequency. The desired surface-consistent components are model parameters, and model optimization is used to solve for the surface-consistent components. The surface-consistent components may include filter transfer functions for each source location, each receiver location, and for propagation (302) through each region (301) of the surface that exhibits lateral variation.Type: GrantFiled: June 19, 2009Date of Patent: October 8, 2013Assignee: ExxonMobil Upstream Research CompanyInventor: Christine E. Krohn
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Patent number: 8509028Abstract: The invention discloses a way to recover separated seismograms with reduced interference noise by processing vibroseis data recorded (or computer simulated) with multiple vibrators shaking simultaneously or nearly simultaneously (200). A preliminary estimate of the separated seismograms is used to obtain improved seismograms (201). The preliminary estimate is convolved with the vibrator signature and then used to update the seismogram. Primary criteria for performing the update include fitting the field data and satisfying typical criteria of noise-free seismograms (202). Alternative ways to update are disclosed, including signal extraction, modeled noise extraction, constrained optimization based separation, and penalized least-squares based separation. The method is particularly suited for removing noise caused by separating the combined record into separate records for each vibrator, and is advantageous where the number of sweeps is fewer than the number of vibrators (200).Type: GrantFiled: June 26, 2012Date of Patent: August 13, 2013Assignee: ExxonMobil Upstream Research CompanyInventors: Ramesh Neelamani, Christine E. Krohn, Jerry Krebs, Max Deffenbaugh, John Anderson
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Publication number: 20130146282Abstract: Method for estimating fluid heterogeneity in a subsurface region from seismic wave attenuation or velocity dispersion that is either measured or extracted from geophysical data (210). A rock physics model in the form of a mathematical relationship is selected that relates attenuation or velocity to frequency and to physical properties that are related to fluid heterogeneity (220). The model, or asymptotes (230) representing the model's behavior at frequency extremes, is inverted (240) and that relationship is used to obtain (250) one or more of the physical properties related to fluid heterogeneity, such as characteristic length scale for fluid saturation heterogeneities (270) and relative volume fractions of the fluids saturating the pore space (280).Type: ApplicationFiled: September 11, 2012Publication date: June 13, 2013Inventors: Julianna J. Toms, Christine E. Krohn, Enru Liu
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Publication number: 20130114375Abstract: Method for separating different seismic energy modes in the acquisition (65) of seismic survey data by using sensors that preferentially record a single mode (63), optionally combined with a source that preferentially transmits that mode.Type: ApplicationFiled: May 23, 2011Publication date: May 9, 2013Inventors: Mark A. Meier, Christine E. Krohn, Marvin L. Johnson, Michael W. Norris, Mat Walsh, Graham A. Winbow
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Patent number: 8428925Abstract: Method for reducing the time needed to perform geophysical inversion by using simultaneous encoded sources in the simulation steps of the inversion process. The geophysical survey data are prepared by encoding (3) a group of source gathers (1), using for each gather a different encoding signature selected from a set (2) of non-equivalent encoding signatures. Then, the encoded gathers are summed (4) by summing all traces corresponding to the same receiver from each gather, resulting in a simultaneous encoded gather. (Alternatively, the geophysical data are acquired from simultaneously encoded sources.) The simulation steps needed for inversion are then calculated using a particular assumed velocity (or other physical property) model (5) and simultaneously activated encoded sources using the same encoding scheme used on the measured data. The result is an updated physical properties model (6) that may be further updated (7) by additional iterations.Type: GrantFiled: January 6, 2012Date of Patent: April 23, 2013Assignee: ExxonMobil Upstream Research CompanyInventors: Jerome R. Krebs, John E. Anderson, Ramesh Neelamani, Charlie Jing, David Hinkley, Thomas A. Dickens, Christine E. Krohn, Peter Traynin
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Patent number: 8352192Abstract: An exemplary method for filtering multi-component seismic data is provided. One or more characteristics of the seismic data corresponding to a relative manifestation of surface wave noise on the different components, such as polarization attributes, are identified. A time-frequency boundary in the seismic data is also identified in the time-frequency transform domain, the time-frequency boundary delineating portions of the seismic data estimated to contain surface wave noise (302). Finally, filtered seismic data are created (306) by removing portions of the seismic data that correspond to the identified characteristics of surface waves and that are within the time-frequency boundary (303).Type: GrantFiled: February 18, 2009Date of Patent: January 8, 2013Assignee: ExxonMobil Upstream Research ComapnyInventors: Mamadou S. Diallo, Marvin L. Johnson, Warren S. Ross, Christine E. Krohn
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Publication number: 20120269034Abstract: The invention discloses a way to recover separated seismograms with reduced interference noise by processing vibroseis data recorded (or computer simulated) with multiple vibrators shaking simultaneously or nearly simultaneously (200). A preliminary estimate of the separated seismograms is used to obtain improved seismograms (201). The preliminary estimate is convolved with the vibrator signature and then used to update the seismogram. Primary criteria for performing the update include fitting the field data and satisfying typical criteria of noise-free seismograms (202). Alternative ways to update are disclosed, including signal extraction, modeled noise extraction, constrained optimization based separation, and penalized least-squares based separation. The method is particularly suited for removing noise caused by separating the combined record into separate records for each vibrator, and is advantageous where the number of sweeps is fewer than the number of vibrators (200).Type: ApplicationFiled: June 26, 2012Publication date: October 25, 2012Inventors: Ramesh Neelamani, Christine E. Krohn, Jerry Krebs, Max Deffenbaugh, John Anderson
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Publication number: 20120109612Abstract: Method for reducing the time needed to perform geophysical inversion by using simultaneous encoded sources in the simulation steps of the inversion process. The geophysical survey data are prepared by encoding (3) a group of source gathers (1), using for each gather a different encoding signature selected from a set (2) of non-equivalent encoding signatures. Then, the encoded gathers are summed (4) by summing all traces corresponding to the same receiver from each gather, resulting in a simultaneous encoded gather. (Alternatively, the geophysical data are acquired from simultaneously encoded sources.) The simulation steps needed for inversion are then calculated using a particular assumed velocity (or other physical property) model (5) and simultaneously activated encoded sources using the same encoding scheme used on the measured data. The result is an updated physical properties model (6) that may be further updated (7) by additional iterations.Type: ApplicationFiled: January 6, 2012Publication date: May 3, 2012Inventors: Jerome R. Krebs, John E. Anderson, Ramesh Neelamani, Charlie Jing, David Hinkley, Thomas A. Dickens, Christine E. Krohn, Peter Traynin
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Patent number: 8121823Abstract: Method for reducing the time needed to perform geophysical inversion by using simultaneous encoded sources in the simulation steps of the inversion process. The geophysical survey data are prepared by encoding (3) a group of source gathers (1), using for each gather a different encoding signature selected from a set (2) of non-equivalent encoding signatures. Then, the encoded gathers are summed (4) by summing all traces corresponding to the same receiver from each gather, resulting in a simultaneous encoded gather. (Alternatively, the geophysical data are acquired from simultaneously encoded sources.) The simulation steps needed for inversion are then calculated using a particular assumed velocity (or other physical property) model (5) and simultaneously activated encoded sources using the same encoding scheme used on the measured data. The result is an updated physical properties model (6) that may be further updated (7) by additional iterations.Type: GrantFiled: September 11, 2007Date of Patent: February 21, 2012Assignee: ExxonMobil Upstream Research CompanyInventors: Jerome R. Krebs, John E. Anderson, Ramesh Neelamani, Charlie Jing, David Hinkley, Thomas A. Dickens, Christine E. Krohn, Peter Traynin
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Publication number: 20110120724Abstract: A method for transforming seismic surface waves into depth profiles of dynamic properties of the soil such as the soil shear modulus or wave velocity or wave attenuation. The invention uses seismic data recorded preferably with a plurality of sources and receivers with a two-stage inversion approach. First, variations in surface-wave waveforms are decomposed (303) into surface-consistent transfer functions preferably for each source, each receiver, and each small region (301) of the surface. Then the transfer functions for each region are inverted (308) to determine soil properties or near-surface properties (such as the shear modulus) as a function of depth. The method can solve for the complex multi-mode nature of the surface waves for a media with both vertical and lateral changes in properties. Errors and limits in resolution for traditional methods from misidentification of ground roll modes or from assuming laterally uniform soil properties are avoided.Type: ApplicationFiled: June 19, 2009Publication date: May 26, 2011Inventor: Christine E. Krohn