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WO2009123790A1 - Procédé de réalisation de pseudomigration q de données sismiques - Google Patents

Procédé de réalisation de pseudomigration q de données sismiques Download PDF

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Publication number
WO2009123790A1
WO2009123790A1 PCT/US2009/033438 US2009033438W WO2009123790A1 WO 2009123790 A1 WO2009123790 A1 WO 2009123790A1 US 2009033438 W US2009033438 W US 2009033438W WO 2009123790 A1 WO2009123790 A1 WO 2009123790A1
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Prior art keywords
seismic data
integration values
derivatives
method recited
model
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PCT/US2009/033438
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English (en)
Inventor
Jonathan Liu
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ExxonMobil Upstream Research Co
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ExxonMobil Upstream Research Co
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/66—Subsurface modeling

Definitions

  • the present invention relates to improving the effectiveness of seismic prospecting.
  • an exemplary embodiment of the present invention relates to a method for improving the accuracy of seismic data by performing pseudo Q migration on the seismic data to compensate for subsurface anomalies in acoustic impedance.
  • An important goal of seismic prospecting is to accurately image subsurface structures commonly referred to as reflectors.
  • Seismic prospecting is facilitated by obtaining raw seismic data during a seismic survey.
  • seismic energy is generated at ground level by, for example, a controlled explosion, and delivered to the earth.
  • Seismic waves are reflected from underground structures and are received by a number of sensors referred to as geophones.
  • the seismic data received by the geophones is processed in an effort to create an accurate mapping of the underground environment.
  • the processed data is then examined with a goal of identifying geological formations that may contain hydrocarbons.
  • Seismic energy that is transmitted in a relatively vertical direction into the earth is the most likely to be reflected by reflectors.
  • Such energy provides meaningful information about subsurface structures.
  • the seismic energy may be undesirably diffused by anomalies in acoustic impedance that routinely occur in the subsurface environment. Diffusion of seismic energy during a seismic survey may cause subsurface features to be incorrectly represented in the resulting seismic data.
  • Acoustic impedance is a measure of the ease with which seismic energy travels through a particular portion of the subsurface environment. Those of ordinary skill in the art will appreciate that acoustic impedance may be defined as a product of density and seismic velocity. Acoustic impedance is typically referred to by the symbol Z.
  • Seismic waves attenuate for a variety of reasons as they travel in a subsurface environment.
  • a quality metric Q is typically used to represent attenuation characteristics of underground formations.
  • Q is inversely proportional to seismic signal attenuation and may range from a value of zero to infinity. Structures with a relatively high Q value tend to transmit seismic waves with little attenuation. Structures that tend to attenuate seismic energy to a greater degree have lower Q values.
  • Q values associated with subsurface structures are used to mathematically alter seismic data values to more accurately represent structures in the subsurface environment. This process may be referred to as "Q migration" by those of ordinary skill in the art.
  • Q migration a seismic data value representing travel of seismic energy through a subsurface structure having a relatively low Q value may be amplified and broadened in spectrum to a greater degree than a data value representing travel of seismic energy through a subsurface structure having a relatively high Q value. Altering the amplitude and phase of data associated with low Q values takes into account the larger signal attenuation that occurs when seismic energy travels through structures having a relatively low Q value.
  • a first known approach is viscoacoustic wave-equation migration, which uses viscoacoustic downward wave propagation to obtain images that have amplitude and phase restoration.
  • An example of this technique is set forth in Yu, Y., R. Lu, and M. Deal, 2002, "Compensation for the Effects of Shallow Gas Attenuation with Viscoacoustic Wave Equation Migration," 72nd Annual International Meeting, SEG, Expanded Abstracts, 2062- 2065, the entire contents of which is hereby incorporated by reference as though fully set forth herein.
  • Viscoacoustic wave-equation migration is often too expensive to be applied to prestack seismic data.
  • a second approach for performing Q migration is known as Kirchhoff Q migration.
  • Kirchoff Q migration uses a Kirchhoff integral with Q compensation to restore amplitude and phase to seismic data that is incorrectly represented because of the location of a corresponding subsurface structure below a structure with a low Q value. This method also has a relatively large computation cost when applied to prestack seismic data.
  • Wave-equation and Kirchoff Q migration can be applied to post-migration seismic data when the input prestack seismic data is unavailable. However, they can only be applied to such data after undoing the effects of migration using a process called demigration. Demigration cannot preserve images away from the attenuation effected areas, so this process may produce artifacts in the resulting seismic image.
  • a method for creating a visualization of a subsurface region based on a plurality of migrated seismic data traces comprises creating a plurality of derivatives of Q integration values based on a velocity model and applying a Q model to the plurality of derivatives of Q integration values to create a plurality of Q integration values.
  • the exemplary method further comprises applying the plurality of Q integration values to the plurality of migrated seismic data traces to create ⁇ -corrected seismic data.
  • the exemplary method additionally comprises creating the visualization of the subsurface region based on the ⁇ -corrected seismic data.
  • a method of creating an optimized seismic data set corresponding to a visualization of a subsurface region based on a plurality of seismic data traces in accordance with an exemplary embodiment of the present invention comprises creating a plurality of derivatives of Q integration values ("derivative values") based on a velocity model.
  • the exemplary method further comprises altering the plurality of derivatives of Q integration values by iteratively applying a successive series of Q models to the plurality of derivatives of Q integration values to create an iterative series of a plurality of Q integration values.
  • the exemplary method additionally comprises creating a plurality of ⁇ -corrected seismic data sets by applying each of the iterative series of the plurality of Q integration values to the plurality of seismic data traces and selecting a one of the plurality of ⁇ -corrected seismic data sets as the optimized seismic data set based on a correspondence between the one of the plurality of ⁇ -corrected seismic data sets with data regarding the subsurface region.
  • a method of evaluating seismic data in accordance with an exemplary alternative embodiment of the present invention is also provided.
  • the seismic data corresponds to a subsurface region and is represented as a plurality of seismic data traces.
  • the exemplary method comprises selecting a plurality of reflection points for each of the plurality of seismic data traces and estimating a reflection angle for each of the plurality of reflection points.
  • the exemplary method further comprises creating a plurality of derivatives of Q integration values based on a velocity model and applying a Q model to the plurality of derivatives of Q integration values to create a plurality of Q integration values.
  • the exemplary method additionally comprises applying the plurality of Q integration values to the plurality of seismic data traces to create ⁇ -corrected seismic data and creating a visualization of the subsurface region based on the ⁇ -corrected seismic data. Finally, the exemplary method comprises evaluating the visualization of the subsurface region to determine whether the subsurface region is likely to contain hydrocarbons.
  • the plurality of derivative values are created by determining rates of change in the velocity model. In another exemplary embodiment, the creation of the plurality of derivative values is based on a plurality of previously determined ray path values.
  • successive ⁇ -corrected seismic data is created based on at least one different Q model without changing the plurality of derivative values.
  • Yet another exemplary embodiment comprises performing a seismic survey to obtain the plurality of seismic data traces.
  • the application of the Q integration values preserves data contained in the plurality of seismic data traces outside areas affected by an anomalously low Q value in the Q model.
  • FIG. 1 is a graphical representation of a subsurface region that is useful in explaining the operation of an exemplary embodiment of the present invention
  • Fig. 2 is a process flow diagram that shows a method in accordance with an exemplary embodiment of the present invention
  • Fig. 3 is a graph showing a velocity model that may be applied to seismic data in accordance with an exemplary embodiment of the present invention
  • Fig. 4 is a graph showing a Q model that may be applied to seismic data in accordance with an exemplary embodiment of the present invention
  • Fig. 5 is a graph showing an adverse effect of an anomalously low Q value on model seismic data
  • Fig. 6 is a graph showing Q integration values computed for the seismic data shown in Fig. 5 in accordance with an exemplary embodiment of the present invention.
  • Fig. 7 is a graph showing an application of Q integration values to restore the seismic data shown in Fig. 5 adverse in accordance with an exemplary embodiment of the present invention.
  • Fig. 1 is a graphical representation of a subsurface region that is useful in explaining the operation of an exemplary embodiment of the present invention.
  • the graph is generally referred to by the reference number 100.
  • the graph 100 shows a water region 101 and a sediment region 102.
  • the water region 101 exhibits a very high Q value, typically represented by a large number such as 999. Accordingly, seismic waves travel through the water region 101 with relatively little attenuation.
  • the sediment region 102 may have a much lower Q value than the water region 101.
  • the Q value of the sediment region 102 may be in the range of about 150.
  • Subsurface anomalies such as gas caps or the like may have extremely low Q values.
  • an anomaly A 103 exhibits a Q value in the range of about 20.
  • an anomaly B 104 also exhibits a Q value in the range of about 20.
  • the low Q values of the anomaly A 103 and the anomaly B 104 result in attenuated seismic data corresponding to deeper subsurface structures.
  • the anomaly A 103 negatively affects the integrity of seismic data in an anomaly A attenuation region 105 that extends below the anomaly A 103. Any seismic energy that travels through the anomaly A 103 will be significantly attenuated when it returns to the surface and is measured. If the anomaly A 103 is disposed above a deposit of hydrocarbons, seismic data that could identify the presence of the deeper reservoir of hydrocarbons could be obscured.
  • This phenomenon is shown in the graph 100 by a series of reflectors 106, 107, 108 and 109. Portions of the reflectors 106, 107, 108 and 109 that are likely to be represented by significantly attenuated seismic data are shown as dashed lines. Data corresponding to portions of the reflectors 106, 107, 108 and 109 that are unlikely to be significantly attenuated by the presence of the anomaly A 103 and the anomaly B 104 are shown as solid lines in Fig. 1.
  • the performance of pseudo Q migration in accordance with an exemplary embodiment of the present invention is intended to restore accurate amplitude, frequency and phase data for seismic energy that is adversely affected by passing through the anomaly A 103 and the anomaly B 104.
  • an exemplary method of performing pseudo Q migration in accordance with the present invention reduces computational cost significantly with respect to known methods of performing Q migration.
  • an exemplary embodiment of the present invention provides restored seismic data without significant loss of accuracy relative to full Q migration.
  • pseudo Q migration in accordance with an exemplary embodiment of the present invention can be used in place of a full Q migration or to build a Q model for a full Q migration.
  • pseudo Q migration in accordance with an exemplary embodiment of the present invention works in the post-migrated domain, so it avoids demigration. This is extremely helpful in cases where the original seismic input traces are not available.
  • ray path refers to a line that is always perpendicular to the travel of seismic waves in an isotropic media.
  • a pseudo Q migration in accordance with an exemplary embodiment of the present invention exploits the assumed independence of ray paths relative to Q models to allow subsequently developed Q models to be applied to post-migration seismic data.
  • the same ray path information may be used to obtain a remigrated image based on an updated or different Q model. In this way, repeated Q migration is avoided when the Q model is changed.
  • An important aspect of pseudo Q migration in accordance with an exemplary embodiment of the present invention involves the building of Q integration table that is used to restore amplitude, frequency and phase values of data corresponding to a migrated trace.
  • Q integration data is computed using the multiplication of a matrix (derivatives of Q integration with respect to a given Q model) and a vector (update of the Q model).
  • the derivatives of Q integration may be computed in part by determining the rate of change in a velocity model.
  • the derivatives of the Q integration are desirably represented as a sparse matrix.
  • pseudo Q migration in accordance with an exemplary embodiment of the present invention comprises a trace-in and trace-out operation, so the computation is essentially a ID processing operation.
  • pseudo Q migration can be implemented in target orientation. An input trace will be remigrated for amplitude and phase restoration only if it is predicted to be affected by a low Q zone such as the anomaly A attenuation region 105.
  • An exemplary embodiment of a pseudo Q migration in accordance with the present invention involves the estimation of ray take-off angles at reflection points. If reflector dips are significant, the dip angles at those reflection points should be measured. For angle gathered migration sections, the ray take-off angles may readily be calculated. For offset gathered migration sections, ray tracing is used to find out specula ray angles at the reflection points.
  • c ⁇ x be a complex velocity in a viscoacoustic velocity field versus the frequency variable ⁇ .
  • c(x) can be represented, as follows:
  • c 0 is the acoustic part of the complex velocity
  • Q is the quality factor representing attenuation
  • ⁇ 0 is a reference frequency.
  • the reference frequency is explained in greater detail in Keers, H., D. W. Vasco, and L. R. Johnson, 2001, “Viscoacoustic Crosswell Imaging Using Asymptotic Waveforms,” Geophysics, 66, 861-870, the entire contents of which are hereby incorporated by reference as if fully set forth herein.
  • the complex travel time can be calculated by where ⁇ (x) is the travel time in the acoustic medium c 0 and [0036]
  • the first term in equation (2) contains the primary kinematic information in migration imaging and can be calculated by ray tracing in an acoustic medium.
  • the second term in equation (2) permits migration to compensate for amplitude loss due to attenuation, and the third term in equation (2) permits migration to compensate for phase distortion due to dispersion. Both the second and third terms depend on T * , the integral of Q ⁇ 1 along the ray path L, as defined in equation (3).
  • T * can be calculated on the same ray paths as used to calculate T. When Q is updated, T remains the same and the change of T * is
  • equation (4) may be rewritten into a matrix form:
  • D is the matrix of derivatives of T * with respect to Q '1 (the derivative values).
  • D contains "the derivatives of Q integration values based on a velocity model," where the term “Q integration vales” is represented by equation (3) and c 0 refers to the velocity model.
  • the matrix D can be pre- calculated and stored because it does not depend on a particular Q model.
  • Ar * may be applied to a migrated trace in the frequency domain by multiplying the factor
  • Fig. 2 is a process flow diagram that shows a method in accordance with an exemplary embodiment of the present invention.
  • the method is generally referred to by the reference number 200.
  • the method 200 begins at block 201, which shows pseudo Q migration input data comprising migrated seismic trace data, a velocity model used to perform the migration and a Q model that is to be applied to the data to restore the effects caused by Q anomalies in the subsurface region.
  • reflection points are selected. Reflection angles for the selected reflection points are estimated, as shown at block 203.
  • the derivatives of Q integration values are computed using the velocity model. Moreover, the derivatives are computed by determining a rate of change in the velocity model, as described above with reference to Fig. 1.
  • the Q model is not dependent on the velocity model.
  • An exemplary embodiment of the present invention exploits the fact that the ray paths followed by seismic energy employed in a seismic survey to obtain the seismic trace data are independent of the Q model.
  • the Q model represents information about the seismic energy attenuation character of a subsurface region as exhibited by the seismic trace data.
  • the Q model may also represent an update relative to a previously-applied Q model.
  • the derivatives of the Q integration values are multiplied by the Q model to create a table of Q integration values, which will restore amplitude, frequency and phase data for each trace of migrated seismic data.
  • the Q integration values are applied to the seismic data at block 206 to create restored or ⁇ -corrected seismic data, as described above with respect to equation (6).
  • the restored or ⁇ -corrected seismic data may be evaluated for the purpose of determining whether the subsurface formation is likely to contain deposits of hydrocarbons.
  • a visualization of a corresponding subsurface environment is created based on the restored seismic data. If it is subsequently desired to justify or revise the Q model to improve the accuracy of the seismic data, the only effort required is to change the Q model and repeat the steps shown in block
  • pseudo Q migration in accordance with an exemplary embodiment of the present invention may be employed to perform tomography with respect to the value of Q.
  • the efficiency of an exemplary embodiment of the present invention allows a user to perform repetitive iterations of data restoration while varying the Q model that is applied. In this manner, a Q model that restores the data in a way that most closely corresponds to expected values of seismic data may be chosen as the correct one for a given dataset.
  • Fig. 3 is a graph showing a velocity model that may be applied to seismic data in accordance with an exemplary embodiment of the present invention.
  • the velocity model is generally referred to by the reference number 300.
  • the graph 300 is shown with various types of black and white hatching for purposes of simplicity and compliance with local patent laws of many countries, but data may be more accurately depicted in a color representation.
  • the velocity model 300 comprises a first velocity region 301, a second velocity region 302, a third velocity region 303 and a fourth velocity region 304.
  • Each of the velocity regions represents velocity data for seismic data travelling in a corresponding region of a subsurface environment.
  • Fig. 4 is a graph showing a ⁇ IQ model that may be applied to seismic data in accordance with an exemplary embodiment of the present invention.
  • the ⁇ IQ model is generally represented by a reference number 400.
  • Those of ordinary skill in the art will appreciate that the graph 400 is shown with various types of black and white hatching for purposes of simplicity and compliance with local patent laws of many countries, but data may be more accurately depicted in a color representation.
  • the ⁇ IQ model 400 contains a first attenuation region 401, a second attenuation region 402 a third attenuation region 403 and a fourth attenuation region 404.
  • Each of the attenuation corresponds to a different value that is related to the attenuation of seismic energy in a subsurface region.
  • the attenuation regions 401 through 404 represent an anomalously low Q region such as a gas cap or the like.
  • Fig. 5 is a graph showing an adverse effect of an anomalously low Q value on model seismic data that has not been corrected for variations in Q value of the subsurface region represented thereby.
  • the model seismic data is generally referred to by the reference number 500.
  • the model seismic data 500 represents seismic data that has undergone an initial migration with only the acoustic velocity model 300 (Fig. 3).
  • the model seismic data 500 contains data representative of a plurality of reflectors 501, 502, 503, 504, 505 and 506.
  • the data corresponding to a subsurface region under the anomalously low Q region 404 (Fig. 4) is shown as a plurality of dashed lines 507 to represent the area of greatest attenuation of seismic energy travelling through the subsurface environment beneath the anomalously low Q region 404 (Fig. 4).
  • Fig. 6 is a graph showing Q integration values computed for the seismic data shown in Fig. 5 in accordance with an exemplary embodiment of the present invention.
  • the Q integration graph is generally referred to by the reference number 600.
  • the data in the Q integration graph 600 is calculated by using equation (5), as described above.
  • the graph 600 is shown with various types of black and white hatching for purposes of simplicity and compliance with local patent laws of many countries, but data may be more accurately depicted in a color representation.
  • the exemplary Q integration graph 600 represents the application of the velocity model 300 (Fig. 3) and the Q model 400 (Fig. 4) to produce Q correction factors to be applied to the model seismic data 500 (Fig. 5) in accordance with an exemplary embodiment of the present invention.
  • the Q integration data contains data in a first Q integration region 601, a second Q integration region 602, a third Q integration region 603 and a fourth Q integration region 604.
  • Each of the Q integration regions represents an amplification value that is to be applied to seismic data to compensate for the variation in Q value of the subsurface environment represented by the Q model 400 (Fig. 4).
  • Fig. 7 is a graph showing an application of Q integration values shown in Fig.
  • the restored seismic data is generally referred to by the reference number 700.
  • the restored seismic data 700 contains data representative of a plurality of reflectors 701, 702, 703, 704, 705 and 706.
  • the data corresponding to the reflectors 701, 702, 703, 704, 705 and 706 is shown as solid lines to represent that the data has been compensated for varying values of Q in the subsurface region as a result of the application of the Q integration data 600 (Fig. 6) to the model seismic data 500 (Fig. 5).
  • the following example is an illustration of the efficiency that may be obtained using an exemplary embodiment of the present invention.
  • An actual set of seismic data may comprise input traces of time migration cubes of four (4) angles, each cube having about five million traces.
  • a full Kirchhoff Q migration would require the performance of an initial demigration on the data. To perform the demigration, each cube would take approximately two months on 129 CPUs in a Linux computing environment.
  • Kirchoff Q migration does not preserve the image outside the low Q attenuation region because demigration is not the exact inverse of the migration.
  • pseudo Q migration in accordance with an exemplary embodiment of the present invention works directly on the migrated data, so no demigration is needed.
  • each cube would take only about two days on one CPU. More importantly, the image after the pseudo Q migration is preserved outside the Q affected attenuation regions.
  • pseudo Q migration provides an alternative way to restore amplitude and phase to seismic data.
  • Such an exemplary pseudo Q migration works on data in a post-migrated domain.
  • pseudo Q migration in accordance with an exemplary embodiment of the present invention is flexible in that it may be applied to data that has been migrated in a wide variety of migration types.
  • pseudo Q migration in accordance with an exemplary embodiment of the present invention is both efficient and cost effective relative to known methods of performing a full Q migration of seismic data.
  • an exemplary embodiment of the present invention can be used for updating a Q model that has been previously applied to the seismic data.

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  • Engineering & Computer Science (AREA)
  • Remote Sensing (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Acoustics & Sound (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geology (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • General Physics & Mathematics (AREA)
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  • Geophysics And Detection Of Objects (AREA)

Abstract

La présente invention concerne un procédé permettant la création d’une visualisation d’une zone souterraine basée sur une pluralité de traces de données sismiques migrées (201). Un mode de réalisation représentatif du procédé comprend la création d’une pluralité de dérivés de valeurs Q d’intégration sur la base d’un modèle de vitesse (204) et l’application d’un modèle Q à la pluralité de dérivés de valeurs Q d’intégration pour créer une pluralité de valeurs Q d’intégration (205). Le procédé représentatif comprend également l’application de la pluralité de valeurs Q d’intégration à la pluralité de traces de données sismiques migrées pour créer des données sismiques β-corrigées (206). Le procédé représentatif comprend en outre la création de la visualisation de la surface souterraine sur la base des données sismiques β-corrigées.
PCT/US2009/033438 2008-03-31 2009-02-06 Procédé de réalisation de pseudomigration q de données sismiques Ceased WO2009123790A1 (fr)

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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2598907C1 (ru) * 2012-11-28 2016-10-10 Эксонмобил Апстрим Рисерч Компани Сейсмическая отражательная q-томография
WO2017058440A1 (fr) * 2015-10-02 2017-04-06 Exxonmobil Upstream Research Company Inversion de champ d'ondes complet à compensation q

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US6278950B1 (en) * 2000-03-02 2001-08-21 Exxonmobil Upstream Research Co. Turning-wave amplitude inversion
US20060056272A1 (en) * 2004-09-13 2006-03-16 Chevron U.S.A. Inc. Methods for earth modeling and seismic imaging using interactive and selective updating
US20060265132A1 (en) * 2005-05-13 2006-11-23 Chevron U.S.A. Inc. Method for estimation of interval seismic quality factor

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6278950B1 (en) * 2000-03-02 2001-08-21 Exxonmobil Upstream Research Co. Turning-wave amplitude inversion
US20060056272A1 (en) * 2004-09-13 2006-03-16 Chevron U.S.A. Inc. Methods for earth modeling and seismic imaging using interactive and selective updating
US20060265132A1 (en) * 2005-05-13 2006-11-23 Chevron U.S.A. Inc. Method for estimation of interval seismic quality factor

Cited By (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2598907C1 (ru) * 2012-11-28 2016-10-10 Эксонмобил Апстрим Рисерч Компани Сейсмическая отражательная q-томография
WO2017058440A1 (fr) * 2015-10-02 2017-04-06 Exxonmobil Upstream Research Company Inversion de champ d'ondes complet à compensation q
KR20180059539A (ko) * 2015-10-02 2018-06-04 엑손모빌 업스트림 리서치 캄파니 Q-보상된 전 파동장 반전
CN108139499A (zh) * 2015-10-02 2018-06-08 埃克森美孚上游研究公司 Q-补偿的全波场反演
US10310113B2 (en) 2015-10-02 2019-06-04 Exxonmobil Upstream Research Company Q-compensated full wavefield inversion
RU2693495C1 (ru) * 2015-10-02 2019-07-03 Эксонмобил Апстрим Рисерч Компани Полная инверсия волнового поля с компенсацией показателя качества
AU2016331881B2 (en) * 2015-10-02 2019-07-11 Exxonmobil Upstream Research Company Q-compensated full wavefield inversion
AU2016331881A8 (en) * 2015-10-02 2019-07-18 Exxonmobil Upstream Research Company Q-compensated full wavefield inversion
AU2016331881B8 (en) * 2015-10-02 2019-07-18 Exxonmobil Upstream Research Company Q-compensated full wavefield inversion
KR102020759B1 (ko) 2015-10-02 2019-09-11 엑손모빌 업스트림 리서치 캄파니 Q-보상된 전 파동장 반전

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