AU2002212548A1 - Velocity analysis on seismic data - Google Patents
Velocity analysis on seismic dataInfo
- Publication number
- AU2002212548A1 AU2002212548A1 AU2002212548A AU2002212548A AU2002212548A1 AU 2002212548 A1 AU2002212548 A1 AU 2002212548A1 AU 2002212548 A AU2002212548 A AU 2002212548A AU 2002212548 A AU2002212548 A AU 2002212548A AU 2002212548 A1 AU2002212548 A1 AU 2002212548A1
- Authority
- AU
- Australia
- Prior art keywords
- velocity
- interpolation
- seismic
- stacks
- seismic data
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
Description
VELOCITY ANALYSIS ON SEISMIC DATA
The present invention relates to a method of processing seismic data and provides a technique for computing a stacked line by interpolation between known stacks.
Seismic data are collected using an array of seismic sources and seismic receivers. The data may be collected on land using, for example, explosive charges as sources and geophones as receivers. Alternatively, the data may be collected at sea using, for example, airguns as sources and hydrophones as receivers. After the raw seismic data have been acquired, the reflected signals (known as traces) received by each of the receivers as a result of the process of actuation of a seismic energy source are processed to form a subsurface image. The processing includes the steps of accounting for the separation (known as offset) between sources and receivers and summing related traces together to increase signal/noise ratio (a process known as stacking).
Figure 1 of the accompanying drawings schematically illustrates an idealised source and receiver arrangement arranged along a line. First, second and third sources 1, 2 and 3, respectively, cooperate with first, second and third receivers 4, 5 and 6, respectively. The sources and receiver are arranged about a common midpoint (CMP) 7 for the source/receiver pairs 1, 6; 2, 5; 3, 4. Seismic energy produced from the actuation of each of the sources i, 2 and 3 is reflected from partial reflectors such as 9 and received by each of the receivers 4, 5 and 6. The travel time of the energy from a source to a receiver increases with increasing distance (offset) between the source and the receiver. The travel time is also a function of the depth of the reflectors and of the velocity of propagation of the signal within the subsurface formations.
Figure 2 of the accompanying drawings illustrates the travel time for the situation shown in Figure 1, as the offset increases. The round trip travel time with respect to offset for each of the reflectors defines a curve. In this simplified situation, the curve can be accurately defined by:
t2 (offset) = (offset)2 /(velocity)2 + 12 (zerooffset)
where t is the round trip travel time, offset is the distance between source and receiver and velocity is the speed of propagation of seismic signals within the subsurface formations.
During the processing of the seismic survey data, the traces are assigned to their respective common midpoints such that the geology beneath the line of sources and receivers can be probed at a plurality of positions. A velocity analysis is then performed for each common midpoint and indeed for each reflector 9. This is achieved by specifying a range of hyperbolas, as defined in the above equation, related to a range of velocities and computing the reflection amplitude along all specified hyperbolas. The seismic traces for a plurality of offsets are then converted in accordance with the hyperbolas to equivalent traces having zero offset and the traces are then summed (stacked). The resulting amplitudes at zero offset are examined to determine which hyperbola gives the best result for each of the reflectors of each common midpoint. Figure 3 of the accompanying drawings shows a typical example of velocity analysis at point i, where the velocity function selected by the user varies between a range of known velocities functions.
Once a velocity function has been analyzed for a common midpoint, the seismic data related to the common midpoint are then corrected to zero offset according to the previous equation and then stacked for that particular common midpoint. The stacked trace has an improved signal-noise ratio compared to the traces recorded at the receivers. That process, repeated at each of the common midpoints of the line, produces a stacked seismic line that gives an indication of the geology of the line. The quality of the stacked line is directly related to the quality of the velocity field used for stacking. Stacking a line is a CPU intensive process that necessitates the use of large and powerful machines, especially if it is to be done in real time.
According to a first aspect of the invention, there is provided a seismic data processing method in which a number of seismic stacks are precomputed for known velocity fields which are chosen to span the range of velocities of interest, and the stacks are then arranged in the 3D memory of a graphics computer, using time and position as first
dimensions and the index of the velocity field as the last dimension, to provide a seismic line stacked for a velocity field of interest.
According to a second aspect of the invention, there is provided a method of processing seismic data, comprising the steps of:
(a) precomputing from the seismic data a plurality of seismic stacks at a plurality of positions and for a plurality of predetermined velocity functions which span a range of velocities of interest;
(b) arranging the stacks in a memory of a graphics computer as a three dimensional array with time, position and index of velocity function as the three dimensions of the arrays;
(c) selecting a velocity function within the range of velocities of interest; and
(d) using a graphics program of the computer to derive from the array of stacks a seismic line representing seismic data stacked for the selected velocity function.
The positions may comprise common midpoints of the seismic data.
At least some of the predetermined velocity functions may be selected arbitrarily. The predetermined velocity functions may comprise a first function and a plurality of second functions, each of which is equal to the product of the first function and a respective coefficient. The coefficients may be substantially evenly spaced.
The array may be a rectangular array.
The step (d) may comprise performing an interpolation. The interpolation may comprise interpolating from a set of values in the stacks surrounding each point of the selected velocity function. The interpolation may be a linear interpolation. The interpolation may be a multi linear interpolation. The interpolation may be a trilinear interpolation.
According to a third aspect of the invention, there is provided a computer programmed to perform a method according to the first or second aspect of the invention.
According to a fourth aspect of the invention, there is provided a program for prograniming a computer to perform a method according to the first or second aspect of the invention.
According to a fifth aspect of the invention, there is provided a storage medium for containing a program according to the fourth aspect of the invention.
The present invention replaces the method of conventional stacking with a technique based on interpolation that can be performed very quickly on modern graphics computers.
The invention will be further described, by way of example, with reference to the accompanying drawings, in which:
Figure 1 illustrates diagrammatically a seismic source/receiver arrangement of known type;
Figure 2 is a graph illustrating travel time against offset;
Figure 3 illustrates various velocity functions as velocity against time;
Figure 4 is a block schematic diagram illustrating a computer for performing a method constituting an embodiment of the invention;
Figure 5 is a flow diagram illustrating a method of processing seismic data constituting an embodiment of the invention;
Figure 6 illustrates a three dimensional array of data stored in the memory of the computer shown in Figure 4; and
Figures 7 and 8 illustrate an example of interpolation performed by the method shown in Figure 5.
The computer shown in Figure 4 comprises a central processing unit (CPU) 10 provided with an input arrangement 11 and an output arrangement 12, for example including a display for displaying the results of the processing performed by the CPU 10. The computer has a program memory 13 which contains a computer program for controlling the operation of the CPU 10 to perform a seismic data processing method as described hereinafter. The computer also has a scratchpad memory 14 for temporarily storing data during operation of the CPU 10, including a three dimensional (3D) memory which cooperates with graphics processing software in the program memory 13 to perform graphics processing including interpolation. The computer therefore functions as a graphics computer, such as a Sun or Silicon Graphics workstation or a high end PC having sufficient memory to store a large "cube" of data and a 3D graphics card with texture mapping which supports the OpenGL language from Silicon Graphics to perform the interpolation.
The method performed by the computer shown in Figure 4 is illustrated in Figure 5 and begins with a step 20 which precomputes a plurality of seismic stacks from seismic data supplied to the computer for a plurality of known velocity fields or functions Nls....,Nn. In particular, the computer precalculates a stack for each common midpoint (CMP) and for each velocity field Nj. The known velocity functions are selected so as to span a range of velocities of interest. These known velocity functions may be selected in any suitable way and may be selected essentially arbitrarily or may be based on knowledge or experience associated with the seismic data being processed. For example, one of the velocity functions may be selected in accordance with any suitable criteria and the remaining known velocity functions may be equal to the product of the known velocity function and a set of coefficients. For example, the velocity functions may differ from each other by fixed percentages or fixed ratios to provide evenly spaced velocity functions spanning the range of velocities of interest.
The stacks formed in the step 20 are then arranged as a 3D array of stacks in the memory 14 in a step 21. For example, as shown in Figure 6, the stacks are arranged in a rectangular 3D array as a cube of data with the vertical downward dimension representing increasing time, the right hand horizontal axis representing common
midpoint number, and the depth axis into the plane of Figure 6 representing the velocity function index with the velocity functions being indexed in increasing order of velocity.
In the 3D space containing the cube of stacked seismic data, any selected or chosen velocity function or field is represented by a velocity surface S as illustrated in Figure 4 (provided that the values of the selected surface lie within the range of velocities spanned by the known velocity functions, for example between the extreme or end functions Nι and Nn). As shown by the step 22 in Figure 5, a velocity function is selected for further processing of the seismic data by a user and this determines the velocity surface S onto which the seismic data can be projected.
A step 23, for example performed within the graphics card, performs interpolation effectively so as to define a "stacked" line of seismic data based on interpolating onto the surface S from the individual samples of the stacks within the data cube which surround each point of the surface S. Although this processing does not yield a true stack, it provides a representation thereof and can be performed relatively quickly, for example in real time, using relatively modest hardware and software. A specific example of an interpolation technique will be described hereinafter.
A step 24 outputs the seismic line, for instance by displaying it on a display of the output arrangement 12 of the computer. A step 25 determines whether a new velocity function has been selected. Until a new function is selected, the output for the existing velocity function S remains available. A user may therefore examine the result of the processing in the form of the stacked line and may decide select a new function, for example by changing the velocity function or chosing a different function. When a new velocity function is selected, control returns to the step 23, which performs a fresh interpolation based on the new function.
Although the stacked traces shown in Figure 6 are illustrated as continuous traces, they are in fact sampled and digitised so that each of the stacks comprises a plurality of digital codes representing the instantaneous sampled amplitude at discrete time points. The cube or space of 3D data is thus effectively divided into a plurality of cells, each of
which is cuboidal and has at its vertices eight stack samples S(i,j,k),...., S(i+1, j+l,k+l) as illustrated in Figure 7. The coordinate axis are shown again in Figure 7 with the common midpoint (CMP) index increasing towards the right in the horizontal or x dimension, time increasing downwardly in the vertical or y dimension, and velocity function index increasing in the depth or z dimension into the plane of Figure 7. The sample which occupies the top front left vertex of the cell is labelled as S(i,j,k) and the remaining seven samples at the other verticies are labelled in accordance with the convention of the axes as described hereinbefore. A sample Sp is illustrated within the cell at a point on the velocity surface S at which it is desired to calculate the "output sample" for the selected velocity function. Thus, the cell illustrated in Figure 7 is one of the cells intersected by the velocity surface S and the value of each sample Sp within a respective cell is calculated by the graphics card by interpolation.
Figure 8 illustrates the position 30 at which the sample Sp is to be calculated within the same cell as illustrated in Figure 7. The point 30 may be anywhere within the cell, including the surfaces, edges and verticies thereof as well as internally within the volume of the cell. Without any loss of generality, the position of the point 30 can be represented by the distances a, ....,f from the various faces of the cuboidal cell. Thus, the point 30 is at a distance a from the front face and b from the rear face, a distance c from the top face and d from the bottom face, and a distance e from the left face and f from the right face, where any of the distances may be zero so that the position of the point 30 can be specified anywhere within the cell including on the external surface thereof.
The graphics card within the computer shown in Figure 4 performs a linear interpolation in order to calculate the value or amplitude of the sample Sp from the samples S(i,j,k),....,S(i+l, j+1, k+1) in accordance with a multilinear (in this case trilinear) interpolation which may be represented as follows:
Sp = (a.d.s.S(i, j, k + l) + b.d.f.S(i, j, k) + a.c.f.S(i, j + 1, k + 1)
+ b.c.f.S(i, j + 1, k) + a.d.e.S(i + 1, j, k + l) + b.d.e.S(i + 1, j, k) + a.c.e.S(i + 1, j + 1, k + 1) + b.c.e.S(i + l,j + 1, k)) /((a + b)(c + d)(e + /))
The interpolation is performed for every cell of the cube of data intersected by the velocity surface S and thus provides a representation or approximation of a stacked line. This may be repeated for a plurality of lines to give a 3D representation of the subsurface structure of the earth represented by the seismic data.
Any suitable interpolation method may be performed within the step 23. For example, any suitable software, such as existing graphics card software, maybe used.
It is thus possible to provide a technique which allows a good representation of a stacked line to be derived relatively quickly and with relatively inexpensive hardware and software. This may be used, for example, in real time. Also, different velocity functions can be tried relatively quickly in order to allow a user to choose the best such function to fit the seismic data. When an optimum velocity function has been selected, it may be used for re-stacking of the seismic traces.
Claims (15)
1. A seismic data processing method in which a number of seismic stacks are precomputed for known velocity fields which are chosen to span the range of velocities of interest, and the stacks are then arranged in the 3D memory of a graphics computer, using time and position as first dimensions and the index of the velocity field as the last dimension, to provide a seismic line stacked for a velocity field of interest.
2. A method of processing seismic data, comprising the steps of:
(a) precomputing from the seismic data a plurality of seismic stacks at a plurality of positions and for a plurality of predetermined velocity functions which span a range of velocities of interest;
(b) arranging the stacks in a memory of a graphics computer as a three dimensional array with time, position and index of velocity function as the three dimensions of the array;
(c) selecting a velocity function within the range of velocities of interest; and
(d) using a graphics program of the computer to derive from the array of stacks a seismic line representing seismic data stacked for the selected velocity function.
3. A method as claimed in claim 2, in which the positions comprise common midpoints of the seismic data.
4. A method as claimed in claim 2 or 3, in which at least some of the predetermined velocity functions are selected arbitrarily.
5. A method as claimed in claim 4, in which the predetermined velocity functions comprise a first function and a plurality of second functions, each of which is equal to the product of the first function and a respective coefficient.
6. A method as claimed in claim 5, in which the coefficients are substantially evenly spaced.
7. A method as claimed in any one of claims 2 to 6, in which the array is a rectangular array.
8. A method as claimed in any one of claims 2 to 7, in which the step (d) comprises performing an interpolation.
9. A method as claimed in claim 8, in which the interpolation comprises interpolating from a set of values in the stacks surrounding each point of the selected velocity function.
10. A method as claimed in claim 8 or 9, in which the interpolation is a linear interpolation.
11. A method as claimed in claim 10, in which the interpolation is a multilinear interpolation.
12. A method as claimed in claim 11, in which the interpolation is a trilinear interpolation.
13. A computer programmed to perform a method as claimed in any one of the preceding claims.
14. A program for programming a computer to perform a method as claimed in any one of claims 1 to 12.
15. A storage medium containing a program as claimed in claim 14.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB0027372 | 2000-11-09 | ||
| GB0027372A GB2368911A (en) | 2000-11-09 | 2000-11-09 | Computing a stacked seismic line by interpolation between known stacks |
| PCT/GB2001/004977 WO2002039144A1 (en) | 2000-11-09 | 2001-11-09 | Velocity analysis on seismic data |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| AU2002212548A1 true AU2002212548A1 (en) | 2002-07-25 |
| AU2002212548B2 AU2002212548B2 (en) | 2006-07-06 |
Family
ID=9902863
Family Applications (2)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| AU2002212548A Ceased AU2002212548B2 (en) | 2000-11-09 | 2001-11-09 | Velocity analysis on seismic data |
| AU1254802A Pending AU1254802A (en) | 2000-11-09 | 2001-11-09 | Velocity analysis on seismic data |
Family Applications After (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| AU1254802A Pending AU1254802A (en) | 2000-11-09 | 2001-11-09 | Velocity analysis on seismic data |
Country Status (11)
| Country | Link |
|---|---|
| US (1) | US6996028B2 (en) |
| EP (1) | EP1334375B1 (en) |
| CN (1) | CN100354655C (en) |
| AT (1) | ATE275272T1 (en) |
| AU (2) | AU2002212548B2 (en) |
| CA (1) | CA2428541A1 (en) |
| DE (1) | DE60105309D1 (en) |
| EA (1) | EA200300546A1 (en) |
| GB (1) | GB2368911A (en) |
| NO (1) | NO20032066L (en) |
| WO (1) | WO2002039144A1 (en) |
Families Citing this family (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102998704B (en) * | 2012-12-13 | 2013-07-17 | 东北石油大学 | Geophysical exploration seismic data processing method |
| US10267934B2 (en) * | 2015-01-13 | 2019-04-23 | Chevron U.S.A. Inc. | System and method for generating a depositional sequence volume from seismic data |
| US10067255B2 (en) | 2015-09-04 | 2018-09-04 | Saudi Arabian Oil Company | Automatic quality control of seismic travel time |
| CN106569261A (en) * | 2015-10-10 | 2017-04-19 | 中国石油化工股份有限公司 | Seismic data velocity interpolation method and system |
| US10386519B2 (en) | 2015-12-18 | 2019-08-20 | Saudi Arabian Oil Company | Automated near surface analysis by surface-consistent refraction methods |
| US10996358B2 (en) * | 2017-08-18 | 2021-05-04 | Saudi Arabian Oil Company | Image-guided velocity interpolation using a mask cube |
| US11531129B2 (en) | 2019-05-30 | 2022-12-20 | Saudi Arabian Oil Company | Picking seismic stacking velocity based on structures in a subterranean formation |
Family Cites Families (18)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4479205A (en) * | 1981-11-16 | 1984-10-23 | Mobil Oil Corporation | Method of migrating seismic data without dependency on velocity |
| CN85106381B (en) * | 1985-08-24 | 1987-04-29 | 菲利普石油公司 | seismic data processing |
| US4766574A (en) * | 1987-03-31 | 1988-08-23 | Amoco Corporation | Method for depth imaging multicomponent seismic data |
| US4813027A (en) | 1987-07-17 | 1989-03-14 | Arabian American Oil Company | Method and apparatus for enhancing seismic data |
| US4849887A (en) * | 1987-08-28 | 1989-07-18 | Amoco Corporation | Horizon velocity analysis |
| US4984220A (en) * | 1989-03-06 | 1991-01-08 | Amoco Corporation | Geophysical exploration using velocity spectra regional coherency peaks |
| US5058079A (en) * | 1990-11-27 | 1991-10-15 | Amoco Corporation | Geophysical exploration using velocity picking from trial velocity function sorted time-coherency traces |
| US5394325A (en) * | 1993-04-07 | 1995-02-28 | Exxon Production Research Company | Robust, efficient three-dimensional finite-difference traveltime calculations |
| US5513150A (en) * | 1993-06-30 | 1996-04-30 | Atlantic Richfield Company | Method of determining 3-D acoustic velocities for seismic surveys |
| US5657223A (en) * | 1994-06-03 | 1997-08-12 | Exxon Production Research Company | Method for seismic data processing using depth slice decomposition |
| US5629904A (en) * | 1994-11-30 | 1997-05-13 | Paradigm Geophysical, Ltd. | Migration process using a model based aperture technique |
| GB9508525D0 (en) * | 1995-04-27 | 1995-06-14 | Geco As | Method of processing seismic data |
| US5995904A (en) * | 1996-06-13 | 1999-11-30 | Exxon Production Research Company | Method for frequency domain seismic data processing on a massively parallel computer |
| US5978314A (en) * | 1997-03-21 | 1999-11-02 | Exxon Production Research Company | Method for determining seismic velocities |
| GB9717409D0 (en) * | 1997-08-15 | 1997-10-22 | Geco Prakla Uk Ltd | A method of processing seismic data |
| US6049759A (en) * | 1998-01-16 | 2000-04-11 | Bp Amoco Corporation | Method of prestack 3-D migration |
| US6128580A (en) * | 1998-04-17 | 2000-10-03 | Bp Amoco Corporation | Converted-wave processing in many-layered anisotropic media |
| US6493634B1 (en) * | 1999-05-14 | 2002-12-10 | Exxonmobil Upstream Research Company | Method for determining stacking velocity parameters or other reflection geometry information from seismic gather data using multiple attributes and 3-D visualization |
-
2000
- 2000-11-09 GB GB0027372A patent/GB2368911A/en not_active Withdrawn
-
2001
- 2001-11-09 WO PCT/GB2001/004977 patent/WO2002039144A1/en not_active Application Discontinuation
- 2001-11-09 CN CNB018185932A patent/CN100354655C/en not_active Expired - Fee Related
- 2001-11-09 AU AU2002212548A patent/AU2002212548B2/en not_active Ceased
- 2001-11-09 EP EP01980760A patent/EP1334375B1/en not_active Expired - Lifetime
- 2001-11-09 EA EA200300546A patent/EA200300546A1/en unknown
- 2001-11-09 AU AU1254802A patent/AU1254802A/en active Pending
- 2001-11-09 DE DE60105309T patent/DE60105309D1/en not_active Expired - Lifetime
- 2001-11-09 AT AT01980760T patent/ATE275272T1/en not_active IP Right Cessation
- 2001-11-09 CA CA002428541A patent/CA2428541A1/en not_active Abandoned
- 2001-11-09 US US10/416,245 patent/US6996028B2/en not_active Expired - Fee Related
-
2003
- 2003-05-08 NO NO20032066A patent/NO20032066L/en not_active Application Discontinuation
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