WO2000019240A2 - Attribut de variation d'amplitude fonde sur le decalage et analyse de contraste de la propriete des roches pour des donnees de releve sismique - Google Patents

Attribut de variation d'amplitude fonde sur le decalage et analyse de contraste de la propriete des roches pour des donnees de releve sismique Download PDF

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WO2000019240A2
WO2000019240A2 PCT/IB1999/001264 IB9901264W WO0019240A2 WO 2000019240 A2 WO2000019240 A2 WO 2000019240A2 IB 9901264 W IB9901264 W IB 9901264W WO 0019240 A2 WO0019240 A2 WO 0019240A2
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attribute
data
consists essentially
coefficients
avo
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PCT/IB1999/001264
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WO2000019240A3 (fr
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Michael Kelly
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Pgs Seres As
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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
    • G01V1/284—Application of the shear wave component and/or several components of the seismic signal
    • G01V1/286—Mode conversion
    • 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
    • G01V1/30—Analysis
    • 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
    • G01V1/30—Analysis
    • G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles

Definitions

  • the present invention is directed, in general, to the use of amplitude variation as a function of offset (AVO) attribute analysis of common mid point (CMP) seismic reflection data, and in particular to the relation of AVO data to rock properties.
  • AVO offset
  • CMP common mid point
  • acoustic energy is applied to the earth's surface. As the energy travels downward, it is reflected from subsurface interfaces back to the earth's surface. The amplitude of the reflected energy is normally recorded in the form of a series of time samples. By plotting these amplitudes versus a time scale, a representation of the locations and shapes of the subsurface interfaces is generated. The depths of the various interfaces correspond generally to the time of arrival of the various signals.
  • CDP common depth point
  • CMP common midpoint
  • the B characteristic represents the rate at which the reflected signal amplitudes vary relative to the squared sine of the incident angle or the rate of change of the amplitude with the offset. While the A and B characteristics resulting from traditional amplitude variation as a function of offset analysis are dependent upon subsurface structure (that is, the interfaces between rock layers of differing types), they do not indicate whether any of the layers contain hydrocarbons, nor can they be interpreted to determine specific rock properties. Therefore, there is a need for a method and system for detern ining rock property information from AVO data.
  • a number of methods have attempted to analyze the AVO attribute response of CMP seismic gathers to predict the presence of hydrocarbons in the earth's subsurface.
  • Previous techniques have sought to analyze the AVO attribute response in terms of the compression waves (P -waves) that propagate through the earth's subsurface and are reflected from the subsurface layers, using a line to represent the attributes of the AVO data.
  • the amplitude variation with offset of pressure wave (a.k.a. "P-wave”) data is plotted, approximated as a line.
  • the intersection of the line and the slope are used to interpret likelihood of hydrocarbon structure.
  • the intersection attribute of AVO data and the slope attribute cannot be related to rock properties, such as density, change in shear-wave (a.k.a.
  • S- wave S- wave velocity ( ⁇ Vs/Ns) or change in P-wave velocity ( ⁇ Vp/Vp).
  • ⁇ Vs/Ns reflected shear waves
  • ⁇ Vp/Vp P-wave velocity
  • a portion of the propagating P-waves are converted into reflected shear waves (S-waves) at each subsurface layer and, at the offsets used in seismic exploration, the P-S converted waves can be significant reflections. See Castagna, J.P., "AVO Analysis-Tutorial and Review", pp 3-9 of Offset Depth Reflectivity Theory and Practice of AVO Analysis edited by Castagna and Backus; 1993, Society of Exploration Geophysicists, incorporated herein by reference.
  • S-waves reflected shear waves
  • the methods and systems of the present invention include determining AVO attributes from seismic survey wave data and deriving a relationship between the AVO attributes and specific rock property contrast such as compression velocity (Vp), shear velocity (Vs), and density (p), whether inter- face (cap/reservoir), inter-location (A/B), or inter-time (T1/T2), and the AVO attribute values and their crossplot positions.
  • rock property contrast is used for detection of hydrocarbons in a geologic formation of interest.
  • the methods and systems of the present invention further include techniques for determining and analyzing the connection between rock property contrasts such as compression velocity (Vp), shear velocity (Vs), and density (p), whether inter-face (cap/reservoir), inter-location (A/B), or inter-time (T1/T2), and the attribute values and their crossplot positions.
  • Vp compression velocity
  • Vs shear velocity
  • p density
  • A/B inter-location
  • T1/T2 inter-time
  • Linearized equations providing curve fit parameters and basic functions are disclosed for deriving incident compression wave to reflected compression wave (P-P), incident compression wave to reflected shear wave (P-S), isotropic horizontal reflected wave (S-S H ), isotropic vertical reflected wave (S-S v ) and joint P-P and P-S AVO attributes.
  • various attributes are directly related to specific rock properties.
  • Crossplots and other displays are also generated using the relationships of the attributes to the rock property. Joint AVO attributes, crossplots, and other displays, are interpreted using a combination of relationships between P-P and P-S attributes.
  • the relative displacement of two points in attribute space can be related uniquely to the contrast of the rock properties Vp, Vs, and density, between the two points in real space.
  • At least two amplitude variation as a function of offset (“AVO") attributes are determined for at least one set of seismic traces.
  • the seismic traces include, for example, compression wave traces, shear wave traces, or joint compression wave and shear wave traces, wherein the seismic traces are of a first type and a second type, and at least two AVO attributes are determined for each of the first and second types of seismic traces.
  • the at least two AVO attributes are determined for seismic traces corresponding to a location of interest, and the presence of hydrocarbon properties of the geologic formation at the location of interest are detected using (1) the derived relationship to obtain a rock property contrast associated with the seismic traces corresponding to the location of interest and (2) the obtained rock property contrast to detect hydrocarbons in the geologic formation at the location of interest.
  • a method for determining a rock property from seismic data comprising: (a) assigning an AVO attribute to the rock property based on a combination of coefficients of a reflectivity equation approximating amplitude variation as a function of offset at a first data point; and
  • the coefficients consist essentially of coefficients based on p-p wave data.
  • the reflectivity equation consists essentially of:
  • the attribute consists essentially of B2.
  • the attribute comprises the sum of Bl and B2, twice the sum of Bl and
  • the attribute consists essentially of
  • the attribute consists essentially of (B1+B0) + B2*(l+((l/4)*(Vp/Ns) 2 ).
  • the coefficients consist essentially of coefficients based on p-s wave data.
  • the reflectivity equation consists essentially of:
  • the attribute consists essentially of the negative of Cl. In other alternative embodiments, the attribute consists essentially of one-half the difference between Cl and CO, Bl -BO-CO, and/or 2*B0+C1. In even further alternative embodiments, the attribute consists essentially of twice the difference between Bl and CO, C1+B0-B1 and/or - 2*(Vs Vp)*Cl. In even further alternative embodiments, the attribute consists essentially of, in the alternative: 2*(B0 - Bl) + (4*(Ns/Np)* CO,
  • the coefficients consist essentially of coefficients based on s-s wave data
  • the reflectivity equation consists essentially of:
  • the attribute consists essentially of:
  • the reflectivity equation consists essentially of:
  • the attribute consists essentially of: (3/5)*EO + (1/5)*E1, and/or - (4/5)*E0 + (2/5)*El.
  • the comparing comprises subfracting the value of the attribute at the first data point from a value of the attribute at the second data point.
  • the comparing comprises plotting the value of the attribute at a first data point and at a second data point.
  • the first data point and the second data points are on opposite sides of a reflection interface; while, in yet a further example, the first data point and the second data point are on the same side of a reflection interface. Alternatively, the first data point and the second data point are both in the same reservoir.
  • further steps comprising determining a further rock property from the seismic data by a method comprising: assigning a further ANO attribute to the further rock property based on a further combination of coefficients of a reflectivity equation approximating amplitude variation as a function of offset; and comparing the further AVO attribute at the first data point to the further AVO attribute at the second data point.
  • the further coefficients consist essentially of coefficients based on p-p wave data, p-s wave data, and/or s-s wave data.
  • the comparing steps comprise cross-plotting the attributes, wherein the cross-plot is oriented such that displacement along an axis of the cross-plot is directly related to a change in a single rock property. In certain situations displacement along a first axis of the cross-plot is directly related to a change in a first single rock property and displacement along a second axis of the cross-plot is directly related to a change in a second single rock property.
  • the first data point comprises a first spatial data point and the second data point comprises a second spatial data point.
  • the first data point comprises a first spatial data point at a first time and the second data point comprises the same spatial data point at a different time from the time from the first data point.
  • a method for determining invalid seismic data acquisition assumptions comprising: determining AVO attributes from seismic data, wherein the attributes are dependant upon multiple modes of wave propagation; comparing attributes which are dependant upon similar physical properties at similar locations, wherein a comparing result is generated; and assigning an error to a comparing result that is outside a predetermined acceptance range.
  • the comparing comprises cross- plotting the attributes; while, in another example, the comparing comprises subtracting a first of the attributes from another of the attributes. In still another example embodiment, the comparing comprises a statistical comparison.
  • the determining comprises determining an AVO attribute from a p-p wave mode and determining an AVO attribute from a p-s wave mode, determining an AVO attribute from a p-s wave mode and determining an AVO attribute from a s-s wave mode, or determining an AVO attribute from a s-s v wave mode and determining an AVO attribute from a s-s H wave mode, wherein both attributes are dependent upon a similar physical property.
  • the similar physical property comprises a rock property (e.g. density, ⁇ Vp/Vp, and/or ⁇ Vs/Ns).
  • a system for determining a rock property from seismic data comprising: an assignor of an AVO attribute to the rock property based on a combination of coefficients of a reflectivity equation approximating amplitude variation as a function of offset at a first data point; and a comparator of the AVO attribute at a first data point to the AVO attribute at a second data point.
  • the comparator comprises a subtractor of the value of the attribute at the first data point from a value of the attribute at the second data point.
  • the comparator comprises a plotter of the value of the attribute at a first data point and at a second data point.
  • the first data point and the second data points are on opposite sides of a reflection interface
  • the reflection interface comprises a cap/reservoir interface
  • the first data point and the second data point are on the same side of a reflection interface
  • the first data point and the second data point are both in the same reservoir.
  • a determiner of a further rock property from the seismic data using: an assignor of a further AVO attribute to the further rock property based on a further combination of coefficients of a reflectivity equation approximating amplitude variation as a function of offset; and a comparator of the further AVO attribute at the first data point to the further AVO attribute at the second data point.
  • the assignor of a further AVO attribute and the assignor of an AVO attribute comprise the same assignor.
  • the comparator of the further AVO attribute and the comparator of an AVO attribute comprise the same comparator.
  • a system for determining invalid seismic data acquisition assumptions, comprising: an AVO attribute determiner, dependent upon seismic data, wherein the attributes are dependant upon multiple modes of wave propagation; a comparator of attributes which are dependant upon similar physical properties at similar locations, the comparator generating a comparator result; and an assignor of an error to a comparator result that is outside a predetermined acceptance range.
  • the comparator comprises a cross-plotter of the attributes.
  • the comparator comprises a subtractor of a first of the attributes from another of the attributes.
  • the comparator comprises a statistical comparator.
  • the AVO attribute determiner is dependent upon an AVO attribute from a p-p wave mode and an AVO attribute from a p-s wave mode, wherein both attributes are dependent upon a similar physical property.
  • the similar physical property comprises a rock property (e.g. density, ⁇ Vp/Np, and ⁇ Vs/Ns).
  • a method for determining rock properties from multiple recordings of seismic data, wherein the multiple recordings are of differing types, the method comprising: determining an amplitude relationship from each of the recordings, and determining a set of rock property relationships from the amplitude relationships.
  • the types comprise P-P and P-S. In another example, the types comprise S-S v and S-S P.
  • the determining and amplitude relationship comprises interpolation of the recordings (e.g. cubic spline) and amplitude extraction from the interpolation. In a still further example, application is made of a least square fit to the extraction whereby an amplitude equation for the data results.
  • the extraction comprises "isotime” extraction (a term known to those of skill in the art).
  • the extraction comprises application of a window around a selected time, and the peak within the window is used an extracted amplitude pick, wherein the window comprises a width of about 10 ms, plus or minus the selected time.
  • the extraction comprises: selection of a zero crossing closest a selected time and determining a peak closest the zero crossing.
  • a system for determining rock properties from multiple recordings of seismic data, wherein the multiple recordings are of differing types, the system comprising: means for determining an amplitude relationship from each of the recordings, and means for determining a set of rock property relationships from the amplitude relationships.
  • the types comprise P-P and P-S. In another example, the types comprise S-S v and S-S P.
  • the means for determining and amplitude relationship comprises means for interpolation of the recordings and means for amplitude extraction from the interpolation. In another example, the means for interpolation comprises a means for application of a cubic spline process. In still a further example, the means for amplitude extraction comprises means for application of isotime extraction. Alternatively, the means for amplitude extraction comprises a means for application of a window around a selected time and a means for assigning the peak within the window as an extracted amplitude pick.
  • the means for extraction comprises: means for selection of a zero crossing closest a selected time and means for determining a peak closest the zero crossing.
  • a means for application of a least squares fit to the extraction whereby an amplitude equation for the data results.
  • a system for display of rock properties comprising a first display area showing a seismic data set of a first type a second display area showing a seismic data set of a second type, the second display area being viewable concurrently with the first display area.
  • the first display is of a P-P synthetic data set and a second display area is of a P-S synthetic data set.
  • a means for selecting a horizon of interest from at least one of two data sets of different types wherein a data set of a first type is displayed in the first display and a data set of a second type is displayed in the second display.
  • the means for selecting comprises a mouse.
  • rock properties of the horizon are displayed concurrently with the horizon upon selection of the horizon.
  • P-P type data is displayed in one of the first and the second display areas
  • P-S type data is displayed in the other of the first and the second display areas.
  • a means for displaying rock properties determined from data represented in both the first and second display areas concurrently with the first and the second display areas wherein the means for displaying rock properties determined from data represented in both the first and second display areas concurrently with the first and the second display areas comprises means for displaying rock properties determined jointly from data represented in the first and the second data sets.
  • a method for display of rock properties comprising: displaying a first display area showing a seismic data set of a first type, and displaying a second display area showing a seismic data set of a second type, the second display area being viewable concurrently with the first display area.
  • the first display is of a P-P synthetic data set
  • the a second display area is of a P-S synthetic data set.
  • the step of selecting a horizon of interest from at least one of two data sets of different types wherein a data set of a first type is displayed in the first display and a data set of a second type is displayed in the second display; and, in one specific embodiment, the selecting comprises indication of the horizon of interest with a mouse.
  • rock properties of the horizon are displayed concurrently with the horizon upon selection of the horizon, wherein P-P type data is displayed in one of the first and the second display areas and P-S type data is displayed in the other of the first and the second display areas.
  • the step of displaying rock properties determined from data represented in both the first and second display areas concurrently with the first and the second display areas comprises displaying rock properties determined jointly from data represented in the first and the second data sets.
  • Figure 1 (labeled prior art) illustrates the CMP and CDP technique
  • Figure 2 (labeled prior art) illustrates the amplitude of reflected waves in a CMP gather will vary with increasing distance or offset from its common mid point;
  • Figure 3 illustrates the curve shape interpretation of an incident P-wave to a reflected P-wave (P-P) ANO attributes
  • Figure 4 illustrates the curve shape interpretation of an incident P-wave to a reflected S-wave (P-S) ANO attributes
  • Figures 5 and 6 are crossplots illustrating the ANO attribute combinations of P-P wave and P-S ANO attributes
  • FIG. 7 through 11 illustrate the crossplotting techniques according to the present invention
  • Figure 12 illustrates the relationship between and definitions of the interface, spatial and temporal contrasts
  • Figure 13 illustrates the relationship between interface and spatial contrast
  • Figure 14 illustrates a geologic reservoir having a gas, oil and brine leg using time lapse ANO attributes
  • Figure 15 is a crossplot of two temporal contrast attributes
  • Figure 16 illustrates a geologic reservoir having a gas, oil and brine leg in a reservoir having water saturation
  • Figure 17 illustrates the values of Np and Vs for a porous Gulf of Mexico (“GOM”) sand with pay saturation values of 5%, 50%, and 100%;
  • GOM porous Gulf of Mexico
  • Figures 18-23 illustrate optimum crossplots according to the present invention and corresponding to the reservoir of Figure 16;
  • Figure 24 is a flowchart illustrating the system of the present invention wherein AVO attributes and rock property contrasts are determined from data for seismic traces including shear wave traces.
  • FIG. 25 A and 25B illustrate further embodiments of the invention.
  • Figure 26 and 27 illustrate even further embodiments of the invention.
  • Figure 28 is a block diagram of an example embodiment of the invention.
  • Figure 29 is a block diagram of an example embodiment of the invention.
  • Figures 30A - 30C are block diagrams of example embodiments of the invention.
  • Figure 31 illustrates a example embodiment of the invention.
  • R( ⁇ ) is the theoretical reflectivity amplitude.
  • the first two terms of such an equation are commonly known in the art as the Bortfeld equation.
  • the three-term equation above (BO, Bl and B2) shall be referred to herein as a three-term P-P equation method of the present invention is also practiced according to an alternative embodiment:
  • the three-term equation comprises another three-term P-P equation. Any other algebraically equivalent reflectivity equation is also useful according to the P-P embodiment of the present invention.
  • ⁇ is the P-wave angle of incidence and the coefficients B0, Bl, B2, and A, B, and C are the P-P AVO attributes.
  • the P-P attributes BO, Bl, and B2 have a simple geometric or curve shape interpretation, as illustrated in Figure 3.
  • the relationship of the attributes to the rock property contrasts across an interface can be determined.
  • the novel relationships are given by linearized equations as follows:
  • Vp compressional velocity
  • Vs shear velocity
  • p bulk density
  • ⁇ contrast across an interface
  • Vs/Vp ratio is the average across the interface
  • ⁇ Vp/Np is associated with 2*(B1+B2)
  • ⁇ p/p is associated with 2*(B0-B1-B2)
  • ⁇ Ns/Ns is associated with (Bl-B0)+B2*(l+((l/4)*(Np/Ns) 2 ).
  • the rock properties are cross plotted, wherein a change in the rock property will be associated with hydrocarbon presence, as discussed more fully below.
  • a linearized equation related to the incident P-wave to the reflected S-wave (P-S) AVO attributes wherein the converted wave reflections (S-waves) are a function of the P- wave angle of incidence ( ⁇ ) as follows:
  • g is the average Vp/Vs ratio and wherein the P-S attributes, CO and Cl, are related to the rock property contrast by;
  • P-P and P-S AVO attributes are combined jointly, and relationships are developed between the rock property contrasts and the joint attributes.
  • a joint combination rock property attributes are related to the P-P and P-S AVO attributes as follows:
  • Vp/Ns is approximately two (2).
  • Vp/Vs is approximately two (2) is appropriate for various types of media (e.g., any depositional system whether clastic or carbinate where depth of burial is greater than 2 or 3 thousand feet; older depositional basins satisfy this criteria at sallower depths than younger basins as Gulf of Mexico) and also allows for faster processing of data.
  • the relationship between the rock property contrasts and the combined P-P and P-S AVO attributes comprise:
  • ⁇ p/p 2*(B0 - Bl) + (4*(Vs/Vp)* CO;
  • ⁇ Vs/Vs (Vs/Np)*Cl - (l/2)*(VpNs)*C0;
  • Vp/Ns is not limited, and the relationships are exact to linear order changes of rock properties.
  • Figures 5 and 6 for a ⁇ Vp/Np illustrates an actual response for a water saturation case showing the points falling along the expected 45-degree line. Any deviation from the 45-degree line indicates either processing enors or the presence of anisofropy.
  • the joint AVO attribute combinations provide a clear separation between desirable and undesirable geological structures and a displacement along either axis is associated with the contrast of a single rock property.
  • DO - ('A)* ( ⁇ VsNs + ⁇ p/p);
  • rock property contrasts in terms of the S-S H attributes according to the present invention are as follows;
  • a further embodiment of the invention comprises the cross plotting of the attributes, as described more fully below.
  • a method and system comprise linearized equations related to the isotropic vertical reflected waves (S-S v ) wherein the isotropic vertical wave reflections (S v -waves) as a function of the P-wave angle of incidence ( ⁇ ) as follows:
  • E0 - (H)* ( ⁇ Vs/Vs + ⁇ p/p);
  • Another embodiment comprises the crossplotting of the attributes.
  • the amplitude equations described above are used to determine "joint attributes" and to determine the rock properties based on multiple types (e.g. P-P, P-S, S-S v , and S-S H ) of waves.
  • multiple types e.g. P-P, P-S, S-S v , and S-S H
  • the amplitude equations are expressed in term of the rock properties: ⁇ Vp/Vp, ⁇ Vs/Vs, and ⁇ p/p. Therefore, a simultaneous solution of various combinations of the Amp x . x equations will provide, directly, a value for the rock properties.
  • the various attributes e.g.
  • BO, Bl, B2, CO, Cl, DO, Dl, E0, El, E2) are also desired, they are then calculated according to the above equations relating the attributes to the rock properties.
  • Such a simultaneous solution of amplitude equations from multiple recordings has the advantage that the result is not dependent upon just one recording or on one type of data, but on multiple recordings and/or multiple types of data. It has been found that if the rock property is determined from a process dependent upon only one recording (e.g. only P-P data), the accuracy of the determination is less than if it is determined from a simultaneous solution from multiple types of recordings.
  • the Amp P . P and Amp P . s equations are used to determine the rock properties.
  • the following steps are performed in a computer system: 1) Parameters for a program are selected, including: a) P-P and P-S angular apertures b) Noise reduction methods (e.g. Robust Fit percentage, Use of super gathers, both of which are understood by those of skill in the art, and other methods which will be known to those of skill in the art.) c) Amplitudes are interpolated d) Amplitudes are extracted e) A Vp/Vs value is selected 2) Inversion (i.e. simultaneous solution of the Amp P.P and Amp P.s equations) is performed, resulting in rock property values. It should be noted that no single combination of the above steps is necessary according to the invention, and some steps are eliminated entirely in some embodiments of the invention. For example, no noise reduction might be applied when the signal to noise ratio is substantial.
  • Noise reduction methods e.g. Robust Fit percentage, Use of super gathers, both of which are understood by those of skill in the art, and other methods which will be known to those
  • the peak amplitude may not be present. Accordingly, in one embodiment of the invention (although not all, necessarily), the amplitudes are interpolated. In one such embodiment, a "cubic spline" process (a process known to those of skill in the art) is used. According to other embodiments, other interpolation processes are used, which will also occur to those of ordinary skill.
  • step Id the amplitudes for a given horizon of interest are extracted.
  • the so-called "isotime” method known to those of skill in the art, is used.
  • a time in the record is selected and the value across the gather or bin is picked.
  • a window around the selected time e.g. 10 ms, plus or minus the selected time
  • the peak within that window is used as the pick.
  • the closest zero-crossing near the selected time is found, and the peak from that zero-crossing is used as the selected peak. It will be noted that such a peak may or may not occur within a specific window.
  • a least squares fit is applied to determine the amplitude equation for the data. Referring now to step le, normally the VpNs ratio is presumed to be 2.
  • low frequency estimates of the velocity functions are used to determine the Vp/Vs ratio to be used in the inversion.
  • the methods for such low frequency estimates are known to those of skill in the art.
  • true amplitude data i.e. data in which the relative strength of reflection events from one reflector to another has not been equalized or otherwise distorted
  • a system for determining rock properties from multiple recordings of seismic data comprising: means 2901 for determining an amplitude relationship from each of the recordings, and means 2902 for determining a set of rock property relationships from the amplitude relationships.
  • means 2901 for determining an amplitude relationship comprises: means 2903 for interpolation of the recordings means 2904 for amplitude extraction from the interpolation.
  • the means 2903 for interpolation comprises a means 2905 for application of a cubic spline process. Also seen in Fig. 29, the system further comprises a means 2906 for application of a least squares fit to the extraction whereby an amplitude equation 2907 for the data results.
  • the amplitude extractor comprises means for application of isotime extraction. As before, the extraction is followed by application of a least squares fit to the extraction whereby an amplitude equation for 5 the data results. 159.
  • the means 2904 for amplitude extraction comprises a means 2910 for application of a window around a selected time and a means 2911 for assigning the peak within the window as an extracted 10 amplitude pick. 160.
  • the window comprises a width of about 10 ms plus or minus the selected time
  • a means 2912 is provided for application of a least squares fit to the 15 extraction whereby an amplitude equation for the data results.
  • the means for extraction comprises: means 2920 for selection of a zero crossing closest a selected time, and means 2921 for determining a peak closest the zero crossing. 20 Again, such means are known; and, again, a means 2922 is provided for application of a least squares fit to the extraction, whereby an amplitude equation for the data results.
  • Figure 7 illustrates P-P AVO attributes B0 vs. Bl
  • Figure 8 illustrates P-P AVO attributes B0 - Bl vs. B0 + Bl wherein the displacement associated with each rock property contrast is shown.
  • a displacement in any given direction cannot be uniquely tied to a single rock property contrast.
  • Figure 9 illustrates a further embodiment, in which P- S AVO attributes Cl vs. (1/2)*C1 + CO are crossplotted, and the displacement associated with each rock property contrast is shown.
  • Figures 10 and 11 illustrate still a further embodiment in which joint P-P and P-S AVO attributes Cl vs. 2*(B1-C0) and Cl vs. (2*B0 - Cl), are crossplotted respectively, wherein the displacement associated with each rock property contrast is shown.
  • Figures 9, 10 and 11 illustrate optimal crossplots having joint attributes wherein a displacement along any axis is directly related to the contrast of a single rock property.
  • the crossplot displacements illustrated in Figures 7 through 11 and the concepts related to the illustrated crossplots apply to interface contrast (cap/reservoir) using absolute crossplot location.
  • the concepts apply to location contrasts (A/B) using a Vp/Ns substantially the same at A and B.
  • the concepts apply to temporal contrasts (T1/T2) using an absolute crossplot location and crossplotting Attributes as described below.
  • a general expression of an AVO attribute at a location A has been discovered which can be compared to the same attribute at another location (across an interface or within the same zone) or at the same location, but at a different time.
  • AVO attribute at A is ( ⁇ Vp/V, ⁇ Vs/s, and ⁇ p/p)
  • the interface contrast at B is ( ⁇ Vp/N, ⁇ Ns/s, and ⁇ p/p) B Therefore, the spatial reservoir or cap contrast is:
  • Attrib A ( ⁇ ,* ⁇ Vp/Np + ⁇ 2 * ⁇ Vs/Vs + ⁇ 3 * ⁇ p/p)
  • Attrib B ( ⁇ ,* ⁇ Np/Np + ⁇ 2 * ⁇ Vs/Vs + ⁇ 3 * ⁇ p/p) B '
  • Attrib A - Attrib B ( ⁇ ,* ⁇ Vp/Vp + ⁇ : * ⁇ Vs/Ns + ⁇ 3 * ⁇ p/p) AB(RESERV0IR) - ( ⁇ ,* ⁇ Vp/Vp + ⁇ 2 * ⁇ Ns/Vs + ⁇ 3 * ⁇ p/p) AB(CAP) .
  • a cross-plot of a first attribute (ATTRTBl) and a second attribute (ATTRIB2) is seen for two points in the reservoir (point A and point B).
  • the change in the position of the cross-plot of the two attribute shows that there is a rock property difference in the reservoir and is given by:
  • Attrib B - Attrib A ( ⁇ ,* ⁇ Vp/Np + ⁇ 2 * ⁇ Vs/Ns + ⁇ 3 * ⁇ /p) BA(RESERVOIR)
  • Attrib B - Attrib A ( ⁇ ,* ⁇ Vp/Np + ⁇ 2 * ⁇ Vs/Ns + ⁇ 3 * ⁇ /p) BA(RESERVOIR)
  • joint AVO attributes are calculated from seismic traces acquired at times Tl (Attl T1 and Att2 T1 ) and T2 (Attl T2 and Att2 T2 ) then differences between the above described optimum joint attributes are as follows:
  • the temporal contrasts are used for crossplotting in a manner similar to the other attributes.
  • An advantage of these temporal attributes is that they are related directly to the change in rock properties of the reservoir due to fluid movement caused by the reservoir being produced.
  • Figure 14 illustrates a geologic reservoir with a gas, oil and brine leg. The positions of the legs are indicated for times Tl and T2. It is expected that there will be a zone in which the fluid has changed due to production, while the properties of the reservoir frame and the cap remain constant.
  • Figure 15 illustrates two temporal contrast attributes crossplotted wherein the preprocessing was performed at true amplitude. The displacement direction and distance directly indicate the change in rock properties in that zone, which is directly related to the degree to which the reservoir is swept and whether there are bypass zones or areas of inefficient sweep.
  • a further embodiment method of the present invention provides the quality control processing and calibration using the rock property contrasts calculated from various combinations of attributes.
  • the attribute combinations as discussed for joint P-P and P-S AVO attributes, which co ⁇ espond with a single rock property contrast are crossplotted.
  • the points fall on a 45- degree line as shown in Figures 5 and 6.
  • the points deviate from the line if there are processing problems or if the zones are anisotropic.
  • processing is also checked by producing three crossplots that form each combination of joint attributes indicated above as follows:
  • the ability to robustly determine the percentage of pay vs. brine in any part of a reservoir has been difficult using typical AVO techniques.
  • the method of the present invention provides for robustly detecting hydrocarbons, even in geologic formation having water saturation problems.
  • the discrimination of high from low pay saturation is possible using the method and system of the present invention for any type of reservoir in which the in-situ rock properties of a high pay saturation version of the reservoir are noticeably different than the low pay saturation version, such as in GOM pay sands and North Sea reservoirs.
  • the present invention is not adversely affected whether the reservoir is a low impedance type III GOM pay sand or a high impedance type II carbonate as long as the degree of pay noticeably affects the reservoir's rock properties.
  • a high porosity GOM pay sand is considered in Figures 16 - 23.
  • Figure 16 illustrates this reservoir with a brine, oil, and gas leg. In the case in which the oil leg is missing, the brine sand goes to a variable water saturation gas sand.
  • Figure 17 shows the variation of the values of Vp and Vs for a porous GOM sand having pay saturation values of 5%, 50%, and 100%. The density values vary from 2.35 to 2.10 g/cc linearly with water saturation.
  • the co ⁇ esponding optimum crossplots are shown in Figures 18 - 23 wherein a small circle indicates brine and a small "x" indicates pay.
  • Figure 18 shows the B0 vs.
  • Figure 19 shows the B0 vs. Bl crossplot for the case where Vs and density variations are considered for the various pay saturations.
  • Figure 20 shows the B0 vs. Bl crossplot for the case where Vp, Vs and density variations are considered for the various pay saturations.
  • the crossplots of Figures 18, 19, and 20 correspond to the expected displacements shown in Figure 7.
  • Figure 21 shows the Cl vs. (1/2)*C1 - CO crossplot for the case where Vp, Vs and density variations are considered for the various pay saturations.
  • the crossplot of Figures 21 co ⁇ esponds to the expected displacements shown in Figure 9.
  • Figure 22 shows the Cl vs. 2*(B1 - CO) crossplot for the case where Vp, Vs and density variations are considered for the various pay saturations.
  • the crossplot of Figures 22 corresponds to the expected displacements shown in Figure 10.
  • Figure 23 shows the Cl vs. 2*B0 + Cl crossplot for the case where Vp, Vs and density variations are considered for the various pay saturations.
  • the crossplot of Figures 23 corresponds to the expected displacements shown in Figure 11.
  • a system which includes a plurality of source-receiver pairs for transmitting seismic signals and receiving seismic signals from a plurality of common depth points in the geologic formation, and, for example, a processor and a memory coupled to the processor for processing the seismic signals.
  • the system includes a recording module, an attribute module, a relationship module, and a hydrocarbon detection module wherein hydrocarbons are detected in a geologic formation using AVO attributes and rock property contrasts.
  • the modules are, for example, either hardware based, software based or a combination of hardware and software.
  • Figure 24 is a flow chart illustrating the operation of the recording module 100, the attribute module 105, the relationship module 110, and the hydrocarbon detection module 115.
  • Process starts at block 120 wherein the plurality of source- receiver pairs transmits and receives the seismic signals from a plurality of common depth points in the geologic formation of interest.
  • the recording module 100 records the seismic signals and organizes the seismic signals, per block 130, into gathers of seismic traces wherein each seismic trace corresponds to one of the common depth points.
  • the seismic traces include, for example, shear wave traces only or, for example, include a first type and a second type of seismic traces such as joint compression wave and shear wave related traces.
  • the attribute module 105 determines, for at least one set of seismic traces, at least two amplitude variation as a function of offset ("AVO") attributes using the appropriate linearizing reflectivity equations as previously described, per block 140.
  • the linearizing reflectivity equations define a set of basic functions and curve- fit parameters.
  • the relationship module 110 derives a relationship between the at least two AVO attributes and a specific rock property contrast.
  • the hydrocarbon detection module 115 determines the at least two AVO attributes for seismic traces co ⁇ esponding to a location of interest. Using the derived relationship to obtain a rock property contrast associated with the seismic traces corresponding to the location of interest per block 160, the hydrocarbon detection module 115 detects the presence of hydrocarbons in the geologic formation at the location of interest using the obtained rock property contrast.
  • the P-P, P-S, and joint P-P and P-S AVO attribute crossplots provide unique advantages in extracting from seismic interface, spatial and temporal contrast values for each of the rock properties such as V, Vs, and density (p).
  • the method and system of the present invention provides advantages in determination of water saturation, reservoir quality, fluid type discrimination and time lapse reservoir monitoring.
  • a system 105 for determining a rock property from seismic data held in memory 100.
  • an example embodiment comprises: an assignor 101 of an AVO attribute to the rock property based on a combination of coefficients of a reflectivity equation approximating amplitude variation as a function of offset at a first data point; and a comparator 103 of the AVO attribute at a first data point to the AVO attribute at a second data point.
  • the coefficients consist essentially of coefficients based on p-p wave data. According to an alternative embodiment, the coefficients consist essentially of coefficients based on p-s wave data; while, in even further alternative embodiments, the coefficients are based on s-s wave data.
  • the coefficients are taken from reflectivity equations such as, for example, the following:
  • the attributes consists essentially of: B2, the sum of Bl and B2, twice the sum of Bl and B2, B0-B1-B2 (or some multiple, thereof, for example: 2*(B0-B1-B2), and/or (B1+B0) + B2*(l+((l/4)*(Vp/Ns) 2 ).
  • the attributes consists essentially of: 2*(Ns/Np)*Cl, 2*(B0 - Bl) + (4*(Vs/Vp)* CO,
  • the comparator 103 comprises a subtractor of the value of the attribute at the first data point from a value of the attribute at the second data point.
  • the comparator comprises a plotter 104 of the value of the attribute at a first data point and at a second data point.
  • first data point and second data points are on opposite sides of a reflection interface, for example, a cap/reservoir interface. While in alternative embodiments, the first data point and the second data point are on the same side of a reflection interface, for example, in the same reservoir.
  • a determiner 105' of a further rock property from the seismic data using: an assignor 107 of a further AVO attribute to the further rock property based on a further combination of coefficients of a reflectivity equation approximating amplitude variation as a function of offset; and a comparator 109 of the further AVO attribute at the first data point to the further AVO attribute at the second data point.
  • the further coefficients consist essentially of coefficients based on p-p wave data, p-s wave data, and s-s wave data, with equations as described above.
  • Fig. 27 an alternative to the embodiment of Fig. 26 is seen, in which only one assignor 110 and one comparator 112 are used for each of the first AVO attribute and the further attribute.
  • the modutes 110 and 112 alternate which data is input in such an embodiment.
  • the further coefficients comprise coefficients from the same reflectively equation as in the assigning of the first attribute while in alternative embodiments, the further coefficients comprise coefficients from a reflectively equation different from the reflectively equation used in the assigning of the first attribute.
  • the system allows for attributes to depend on, for example, both p-p coefficients and p-s coefficients.
  • the cross- plot is oriented wherein displacement along an axis of the cross-plot is directly related to a change in a single rock property.
  • Such orientation allows for direct detection of rock property change, as opposed to an orientation in which the single rock property is not axis-aligned.
  • displacement along a first axis of the cross-plot is directly related to a change in a first single rock property and displacement along a second axis of the cross-plot is directly related to a change in a second single rock property.
  • plot includes both physical plotting (e.g. on paper or another display medium (e.g.
  • mapping within a computer memory, wherein the "plot" of the data within the machine is available for use by further automated processing.
  • data point refers to both spatial and temporal data points.
  • location of AVO analysis which are either spatially different (i.e. on different sides of a reflection interface), or temporally different (some spatial location, but different times).
  • a system for determining invalid seismic data acquisition assumptions (e.g. acquisition errors, anisofropy, etc.), comprising: an AVO attribute determiner 120, dependent upon seismic data 122, wherein the attributes are dependant upon multiple modes of wave propagation (e.g. p- p, p-s; and or s-s propagation).
  • AVO attribute determiner 120 dependent upon seismic data 122, wherein the attributes are dependant upon multiple modes of wave propagation (e.g. p- p, p-s; and or s-s propagation).
  • a comparator 124 of attributes which are dependant upon similar physical properties at similar locations generates a comparator result 126, and an assignor 128 of an enor to any comparator result that is outside a predetermined acceptance range is provided.
  • the comparator comprises a cross-plotter of the attributes; while, in another embodiment, the comparator comprises a subtractor of a first of the attributes from another of the attributes. In an even further embodiment, the comparator comprises a statistical comparator. Specific example embodiments of an e ⁇ or assignor 128 will be known to those of skill in the art.
  • a particular method of display is particularly beneficial.
  • a first display area 2801 shows a P-P synthetic data set with noise on the left and a second display area 2804 shows a P-S synthetic data set with noise.
  • a mouse or other indicator is used to select the horizon of interest, shown by anows 2806 and 2808.
  • display area 2810 three different sets of analysis are seen in display areas 2810a, 2810b and 2810c.
  • area 2810a the rock properties are determined from the P-P amplitudes only.
  • area 2810b the rock properties are determined from the P-S amplitudes only.
  • the rock properties are determined from the P-P and P-S amplitudes, jointly.

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Abstract

Des attributs AVO sont déterminés à partir de données d'onde d'un relevé sismique et une relation est établie entre ces attributs AVO et un contraste spécifique de la propriété des roches, dont une relation interfaciale (capuchon/réservoir), de localisation (A/B) ou temporelle (T1/T2). Au moins deux attributs de variation d'amplitude fondés sur le décalage ('AVO') sont déterminés pour au moins un ensemble de traces sismiques. Ces traces sismiques incluent, par exemple, des traces d'onde équivolumique, ou une onde de compression commune et des traces d'onde équivolumique. Les traces sismiques sont d'un premier et d'un deuxième types et au moins deux attributs AVO sont déterminés pour chaque type de trace sismique. Des équations linéarisées fournissant des paramètres d'ajustement de courbe et des fonctions élémentaires sont mises en oeuvre pour déterminer les attributs AVO. Une onde de compression incidente mise en relation avec une onde de compression réfléchie (P-P), une onde de compression incidente mise en relation avec une onde équivolumique réfléchie (P-S), une onde isotrope horizontale réfléchie (S-SH), une onde isotrope verticale réfléchie (S-SV) et des attributs AVO communs P-P et P-S sont déterminés et une relation est établie pour rapporter directement les attributs AVO à des contrastes spécifiques de la propriété des roches. Ces deux attributs AVO sont déterminés pour des traces sismiques correspondant à un emplacement d'intérêt, et la présence de propriétés d'hydrocarbures de la formation géologique à cet emplacement d'intérêt est détectée au moyen de cette relation établie afin d'obtenir un contraste de la propriété des roches associé aux traces sismiques correspondant à l'emplacement d'intérêt, et le contraste de la propriété des roches ainsi obtenu est utilisé pour détecter des hydrocarbures dans la formation géologique, audit emplacement d'intérêt.
PCT/IB1999/001264 1998-09-28 1999-05-19 Attribut de variation d'amplitude fonde sur le decalage et analyse de contraste de la propriete des roches pour des donnees de releve sismique WO2000019240A2 (fr)

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US8705317B2 (en) 2008-12-17 2014-04-22 Exxonmobil Upstream Research Company Method for imaging of targeted reflectors
US8724429B2 (en) 2008-12-17 2014-05-13 Exxonmobil Upstream Research Company System and method for performing time-lapse monitor surverying using sparse monitor data
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CN109541689A (zh) * 2018-11-30 2019-03-29 中铁第四勘察设计院集团有限公司 一种基于反射波能量特征的介质密实度评价方法
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CN111985507A (zh) * 2020-08-28 2020-11-24 东北大学 一种岩体三维点云节理迹线提取方法
CN113588416A (zh) * 2021-05-13 2021-11-02 中铁大桥勘测设计院集团有限公司 一种礁灰岩岩体基本质量分级方法

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WO2000043811A2 (fr) * 1999-01-19 2000-07-27 Bp Corporation North America Inc. Decomposition spectrale permettant l'interpretation de phenomenes sismiques
WO2000043811A3 (fr) * 1999-01-19 2001-02-01 Bp Amoco Corp Decomposition spectrale permettant l'interpretation de phenomenes sismiques
WO2004109336A1 (fr) * 2003-06-04 2004-12-16 Westerngeco, L.L.C. Procede et appareil d'execution d'une analyse de variation d'amplitude avec decalage
WO2008157029A2 (fr) * 2007-06-13 2008-12-24 Schlumberger Canada Limited Détermination de contraste de densité au niveau d'une interface souterraine
WO2008157029A3 (fr) * 2007-06-13 2010-06-10 Schlumberger Canada Limited Détermination de contraste de densité au niveau d'une interface souterraine
US8724429B2 (en) 2008-12-17 2014-05-13 Exxonmobil Upstream Research Company System and method for performing time-lapse monitor surverying using sparse monitor data
US8705317B2 (en) 2008-12-17 2014-04-22 Exxonmobil Upstream Research Company Method for imaging of targeted reflectors
US9146329B2 (en) 2008-12-17 2015-09-29 Exxonmobil Upstream Research Company System and method for reconstruction of time-lapse data
US8483964B2 (en) 2009-06-02 2013-07-09 Exxonmobil Upstream Research Company Estimating reservoir properties from 4D seismic data
US8332154B2 (en) 2009-06-02 2012-12-11 Exxonmobil Upstream Research Company Estimating reservoir properties from 4D seismic data
US9207351B2 (en) 2009-06-26 2015-12-08 Exxonmobil Upstream Research Company Constructing resistivity models from stochastic inversion
WO2019081990A1 (fr) * 2017-10-26 2019-05-02 Chevron U.S.A. Inc. Système et procédé d'évaluation de la présence d'hydrocarbures dans un réservoir souterrain sur la base de données sismiques répétées
US10534100B2 (en) 2017-10-26 2020-01-14 Chevron U.S.A. Inc. System and method for assessing the presence of hydrocarbons in a subterranean reservoir based on time-lapse seismic data
US10718876B2 (en) 2017-10-26 2020-07-21 Chevron U.S.A. Inc. System and method for assessing the presence of hydrocarbons in a subterranean reservoir based on seismic inversions
CN109541689A (zh) * 2018-11-30 2019-03-29 中铁第四勘察设计院集团有限公司 一种基于反射波能量特征的介质密实度评价方法
CN111985507A (zh) * 2020-08-28 2020-11-24 东北大学 一种岩体三维点云节理迹线提取方法
CN111985507B (zh) * 2020-08-28 2023-07-28 东北大学 一种岩体三维点云节理迹线提取方法
CN113588416A (zh) * 2021-05-13 2021-11-02 中铁大桥勘测设计院集团有限公司 一种礁灰岩岩体基本质量分级方法
CN113588416B (zh) * 2021-05-13 2024-02-02 中铁大桥勘测设计院集团有限公司 一种礁灰岩岩体基本质量分级方法

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