CN111257937A - Method for updating seismic velocity of stratum to be drilled - Google Patents
Method for updating seismic velocity of stratum to be drilled Download PDFInfo
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- 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. analysis, for interpretation, for correction
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Abstract
A method of updating seismic velocities of an earth formation to be drilled, comprising: carrying out prestack depth migration by using an initial seismic velocity model of a target area to obtain a common imaging point gather of the target area; based on the common imaging point gather, selecting reflection points with different depths on a track corresponding to a well track of an undrilled area; for each reflection point, respectively obtaining imaging depths corresponding to different reflection angles and ray lengths of corresponding reflection rays in each layer; and determining an updating coefficient in a seismic velocity updating model according to the imaging depth and the ray length of the corresponding reflection ray in each horizon, and updating the initial seismic velocity of the stratum corresponding to each reflection point by using the seismic updating model to obtain the updated seismic velocity. The method can greatly reduce the number of parameters of the traditional seismic tomography, thereby improving the speed modeling efficiency and laying a foundation for correcting the geomechanical model of the stratum to be drilled in real time.
Description
Cross reference to related art
The present application claims the title filed 2018, 11, 30: priority of the chinese patent application CN 201811453357.X, "a method of updating seismic velocities of formations to be drilled", the entire content of which is incorporated herein by reference.
Technical Field
The invention relates to the technical field of oil and gas exploration and development, in particular to a technical method for guiding drilling by geophysical method, and especially relates to a method for updating seismic velocity of a to-be-drilled stratum.
Background
The oil and gas drilling faces increasingly complex geological environments, geological and mechanical characteristics of a target area are accurately described, and the drilling risk can be greatly reduced by reasonably establishing a model of the underground before drilling. At present, the method for establishing the underground model before drilling is mainly carried out by comprehensively using the geophysical and rock mechanics method on the basis of conventional seismic imaging.
The establishment of a velocity model in the seismic imaging process often has a multi-solution problem, which causes great errors in predicted horizons, structures, lithology and mechanical characteristics in certain work areas, and can cause adverse effects on the scientificity and accuracy of drilling design.
Correcting the geomechanical model while drilling requires quickly updating the seismic velocity field information of the formation to be drilled during the actual drilling process. The traditional tomography technology gridds the whole stratum, the number of inversion parameters is increased by the mode, the efficiency is low, and the method is not suitable for the environment while drilling. The articles and patents disclosed so far are silent about the seismic velocity modeling method applicable to this environment.
Disclosure of Invention
In order to solve the above problems, the present invention provides a method for updating seismic velocities of an earth formation to be drilled, the method comprising:
the method comprises the steps of firstly, carrying out prestack depth migration by utilizing an initial seismic velocity model of a target area to obtain a common imaging point gather of the target area, wherein the target area comprises a drilled area and an unwelded area;
secondly, based on the common imaging point gather, selecting reflection points with different depths on a track corresponding to a well track of an undrilled area;
step three, respectively acquiring imaging depths corresponding to different reflection angles and ray lengths of corresponding reflection rays in each layer for each reflection point;
determining an updating coefficient in a seismic velocity updating model according to the imaging depth and the ray length of the corresponding reflection ray in each horizon;
and fifthly, updating the initial seismic velocity of the stratum corresponding to each reflection point by using the seismic updating model according to the updating coefficient to obtain the updated seismic velocity.
According to one embodiment of the invention, the initial seismic velocity model of the drilled area is a seismic velocity model updated with seismic time horizon interpretation result data and real borehole logging data.
According to an embodiment of the invention, in the second step, according to the depth of a reflection point, and the seismic time horizon interpretation result data and the initial seismic velocity data of the next horizon of the horizon, the reflection point corresponding to the next horizon is determined.
According to an embodiment of the present invention, the reflection point corresponding to the next horizon is determined according to the following expression:
wherein the content of the first and second substances,
seismic time horizon interpretation result data, z, representing the jth horizoniAnd zi-1Respectively representing the depth of a reflection point corresponding to the ith layer position and a reflection point corresponding to the (i-1) th layer position in the target area, viRepresenting the initial seismic velocity of the ith horizon,
representing the dip of the formation for the ith horizon.
According to an embodiment of the present invention, in the third step, for each reflection point, an RMO is picked up in the common imaging point gather, and imaging depths corresponding to different reflection angles are obtained according to the RMO.
According to an embodiment of the invention, in the third step, the length of the acquired reflection ray in each horizon is the ray length from the reflection point to the interface between the undrilled area and the drilled area.
According to one embodiment of the invention, in said step four,
determining the seismic velocity deformation corresponding to each reflection point according to the imaging depth and the ray length of the corresponding reflection ray in each horizon;
and determining an updating coefficient in a seismic velocity updating model according to the seismic velocity deformation.
According to an embodiment of the present invention, in the fourth step, the seismic velocity deformation corresponding to each reflection point is determined according to the following expression:
wherein the content of the first and second substances,
representing the initial seismic velocity, theta, of the formation corresponding to the ith reflection point1,iAnd theta2,iTwo different reflection angles, l, respectively representing the ith reflection point1,iAnd l2,iRespectively represent the reflection angle theta1,iAnd theta2,iThe ray length of the corresponding reflected ray in the formation corresponding to the ith reflection point,
and
respectively represent the reflection angle theta1,iAnd theta2,iCorresponding imaging depth, Δ miRepresenting the deformation of the seismic velocity corresponding to the ith reflection point,
and indicating the stratum inclination angle corresponding to the ith reflection point.
In the fourth step, according to an embodiment of the present invention, the update coefficients in the seismic velocity update model are determined according to the following expression:
wherein the content of the first and second substances,
representing the updated seismic velocity of the formation corresponding to the ith reflection point, c0,iAnd c1,iAnd indicating the updating coefficient corresponding to the ith reflection point.
According to one embodiment of the invention, the coefficient c is updated0,iIs 1.
According to an embodiment of the present invention, in the fifth step, the initial seismic velocity of the stratum corresponding to each reflection point is updated according to the following expression:
wherein the content of the first and second substances,
representing the updated seismic velocity of the formation corresponding to the ith reflection point, c0,iAnd c1,iRepresents the updating coefficient corresponding to the ith reflection point,
and representing the initial seismic velocity of the stratum corresponding to the ith reflection point.
The method for updating the seismic velocity of the stratum to be drilled can greatly reduce the quantity of parameters of the traditional seismic tomography, thereby improving the velocity modeling efficiency (in actual use, computer software can rapidly complete the updating and re-modeling of the seismic velocity of the stratum to be drilled within 24 hours), and laying a foundation for correcting the geomechanical model of the stratum to be drilled in real time.
Additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. The objectives and other advantages of the invention will be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required in the description of the embodiments or the prior art:
FIG. 1 is a schematic flow chart of an implementation of a method for updating seismic velocities of a formation to be drilled according to one embodiment of the invention;
FIG. 2 is a schematic diagram of the structure of a target area according to one embodiment of the present invention;
FIG. 3 is a diagram of initial pre-stack depth migration imaging depths, according to one embodiment of the present invention;
FIG. 4 is a schematic diagram of a common imaging point gather, in accordance with one embodiment of the present invention;
FIG. 5 is a schematic illustration of reflected rays according to one embodiment of the present invention;
fig. 6 is a flow chart illustrating an implementation of determining update coefficients according to an embodiment of the present invention.
Detailed Description
The following detailed description of the embodiments of the present invention will be provided with reference to the drawings and examples, so that how to apply the technical means to solve the technical problems and achieve the technical effects can be fully understood and implemented. It should be noted that, as long as there is no conflict, the embodiments and the features of the embodiments of the present invention may be combined with each other, and the technical solutions formed are within the scope of the present invention.
In the following description, for purposes of explanation, numerous specific details are set forth in order to provide a thorough understanding of the embodiments of the invention. It will be apparent, however, to one skilled in the art that the present invention may be practiced without some of these specific details or with other methods described herein.
Additionally, the steps illustrated in the flow charts of the figures may be performed in a computer system such as a set of computer-executable instructions and, although a logical order is illustrated in the flow charts, in some cases, the steps illustrated or described may be performed in an order different than here.
Aiming at the problems in the prior art, the invention provides a novel method for updating the seismic speed of the stratum to be drilled. Fig. 1 shows a schematic flow chart of implementation of the method in this embodiment.
As shown in fig. 1, in this embodiment, in step S101, the method first performs prestack depth migration by using an initial seismic velocity model of a target area, so as to obtain a common imaging point gather of the target area. As shown in fig. 2, in the present embodiment, the target area preferably includes a drilled area and an area to be drilled (i.e., an undrilled area), and the invention preferably primarily updates the seismic velocities of the area to be drilled to obtain more accurate seismic velocity data.
In this embodiment, the initial seismic data of the target area acquired by the method in step S101 is preferably pre-stack seismic data with a central point falling within a certain range around the well (for example, typically, bottom hole displacement plus 3000m-5000m) determined according to the bottom hole displacement size, and an initial seismic velocity model of the corresponding area. Of course, in other embodiments of the present invention, the original reference seismic data of the target area may also be seismic data of other reasonable areas.
When the subsurface formation is horizontal or near horizontal, the position and morphology of the formation as reflected in the horizontal stacking profile corresponds or substantially corresponds to the actual condition of the formation in the subsurface. However, when the formation is dipping or has large variations in attitude, the position and shape of the formation as reflected in the horizontal stacking profile may deviate from the actual situation, and even deviate significantly. In order to correct such a deviation, an offset process is required.
Therefore, in this embodiment, the method performs prestack depth migration on the velocity model of the target region in step S101. It should be noted that, in this embodiment, the velocity model of the drilled area in the target area is an updated velocity model using the seismic time horizon interpretation result data and the actual drilling and logging data.
Specifically, in this embodiment, the method may preferably perform prestack depth migration using a velocity model of the target region by using a ray theory-based migration algorithm such as gaussian beam, kirchhoff, and the like, so as to obtain an imaging profile and a common imaging point gather. Fig. 3 shows an initial prestack depth migration imaging depth diagram in the present embodiment, and fig. 4 shows a common imaging point gather diagram.
Of course, in other embodiments of the present invention, the method may also perform prestack depth migration on the velocity model of the target region in other reasonable manners according to actual needs, and the present invention is not limited thereto.
As shown in fig. 1 again, in the present embodiment, after the prestack depth is shifted, in step S102, based on the common imaging point gather, the method selects reflection points with different depths from the tracks corresponding to the well tracks in the non-drilled area. Specifically, in this embodiment, the method preferably picks up the depth coordinates of the reflection points at different depths on the trajectory corresponding to the well trajectory in step S102, and the picking operation does not need to be particularly precise.
Of course, in other embodiments of the present invention, the method may also adopt other reasonable manners to select the reflection point in step S102 according to actual needs, and the present invention is not limited thereto.
For example, in an embodiment of the present invention, the method may further determine, in step S102, a reflection point corresponding to a next horizon according to the depth of the reflection point corresponding to the one horizon, and seismic time horizon interpretation result data and initial seismic velocity data of the next horizon of the horizon.
Specifically, the method may determine a reflection point corresponding to a next horizon according to the following expression:
wherein the content of the first and second substances,
seismic time horizon interpretation result data, z, representing the jth horizoniAnd zi-1Respectively representing the depth of a reflection point corresponding to the ith layer position and a reflection point corresponding to the (i-1) th layer position in the target area, viRepresenting the initial seismic velocity, θ, of the ith horizoniRepresenting the dip of the formation for the ith horizon.
Thus, reflection points with different depths can be obtained.
After selecting reflection points of different depths on a channel corresponding to a well trajectory of an undrilled area, as shown in fig. 1, in this embodiment, the method preferably obtains, for each reflection point, imaging depths corresponding to different reflection angles and ray lengths of corresponding reflection rays in each horizon in step S103, and determines an update coefficient in the seismic velocity update model according to the imaging depths corresponding to the different reflection angles and the ray lengths of the corresponding reflection rays in each horizon in step S104.
Specifically, in this embodiment, for any reflection point, the method preferably picks up the residual time difference RMO in the common imaging point gather in step S103, and obtains the imaging depths corresponding to different reflection angles according to the residual time difference RMO.
For example, as shown in FIG. 5, the two different reflection angles of the ith reflection point are respectively θ1,iAnd theta2,iThe imaging depths corresponding to the two reflection angles are respectively
And
for the simulated reflected rays corresponding to each reflection angle, in this embodiment, the method preferably traces the reflected rays from the emission point to the surface direction at the specified reflection angle, and the tracing of the reflected rays is preferably to the interface between the drilled area and the unwritten area, and does not need to trace to the surface completely. That is, the total length of the reflected rays acquired by the method within each horizon is preferably the ray length from the reflection point to the interface between the undrilled and drilled regions.
Of course, in other embodiments of the present invention, the method may also use other reasonable ways to determine the imaging depths corresponding to different reflection angles and the ray lengths of the corresponding reflected rays in the respective horizons.
In the embodiment, as shown in fig. 1, the method determines the update coefficients in the seismic velocity update model according to the imaging depth obtained in step S103 and the ray length of the corresponding reflected ray in each horizon in step S104.
As shown in fig. 6, in this embodiment, the method preferably determines, in step S601, a seismic velocity deformation corresponding to each reflection point according to the imaging depth obtained in step S103 and the ray length of the corresponding reflection ray in each horizon, and then determines, in step S602, an update coefficient in the seismic velocity update model according to the seismic velocity deformation.
Specifically, for the ith reflection point, for example, in the present embodiment, the method preferably determines the seismic velocity deformation corresponding to the reflection point according to the following expression in step S601:
wherein the content of the first and second substances,
representing the initial seismic velocity, theta, of the formation corresponding to the ith reflection point1,iAnd theta2,iTwo different reflection angles, l, respectively representing the ith reflection point1,iAnd l2,iRespectively represent the reflection angle theta1,iAnd theta2,iThe corresponding reflection ray has the internal reflection length in the stratum corresponding to the first reflection point,
and
respectively represents,. DELTA.miRepresenting the deformation of the seismic velocity corresponding to the ith reflection point,
and indicating the stratum inclination angle corresponding to the ith reflection point.
According to the expression (2), the method can determine the seismic velocity deformation delta m corresponding to the ith reflection pointi. And the method preferably bases the seismic velocity deformation Δ m corresponding to the ith reflection point in step S602iDetermining update coefficients in the seismic velocity update model using the following expression:
wherein the content of the first and second substances,
representing the updated seismic velocity of the formation corresponding to the ith reflection point, c0,iAnd c1,iIndicating the update coefficient.
In this embodiment, theNew coefficient c0Is 1. Of course, in other embodiments of the present invention, the coefficient c is updated0The value of (b) can also be other reasonable values.
By using the expression (3), the method can determine the update coefficient c corresponding to the ith reflection point0,iAnd c1,i. Based on the same principle, the method can also determine the updating coefficient corresponding to the ith reflection point.
After obtaining the update coefficients, the method may update the initial seismic velocities of the earth formations corresponding to the respective emission points by using the seismic update model in step S105 according to the update coefficients.
Specifically, in this embodiment, the seismic update model may be represented as:
wherein the content of the first and second substances,
representing the updated seismic velocity of the formation corresponding to the ith reflection point, c0,iAnd c1,iRepresents the updating coefficient corresponding to the ith reflection point,
and representing the initial seismic velocity of the stratum corresponding to the ith reflection point.
Based on the principle, the method can update the seismic velocity of the stratum corresponding to each emission point, so that each reflecting surface in the finally obtained common imaging point trace set is leveled.
From the above description, it can be seen that the method for updating the seismic velocity of the stratum to be drilled provided by the invention can greatly reduce the number of parameters of the traditional seismic tomography, thereby improving the velocity modeling efficiency (in actual use, computer software can rapidly complete the updating and re-modeling of the seismic velocity of the stratum to be drilled within 24 hours), and laying a foundation for correcting the geomechanical model of the stratum to be drilled in real time.
It is to be understood that the disclosed embodiments of the invention are not limited to the particular structures or process steps disclosed herein, but extend to equivalents thereof as would be understood by those skilled in the relevant art. It is also to be understood that the terminology used herein is for the purpose of describing particular embodiments only, and is not intended to be limiting.
Reference in the specification to "one embodiment" or "an embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Thus, the appearances of the phrase "one embodiment" or "an embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment.
While the above examples are illustrative of the principles of the present invention in one or more applications, it will be apparent to those of ordinary skill in the art that various changes in form, usage and details of implementation can be made without departing from the principles and concepts of the invention. Accordingly, the invention is defined by the appended claims.
Claims (11)
1. A method of updating seismic velocities of an earth formation to be drilled, the method comprising:
the method comprises the steps of firstly, carrying out prestack depth migration by utilizing an initial seismic velocity model of a target area to obtain a common imaging point gather of the target area, wherein the target area comprises a drilled area and an unwelded area;
secondly, based on the common imaging point gather, selecting reflection points with different depths on a track corresponding to a well track of an undrilled area;
step three, respectively acquiring imaging depths corresponding to different reflection angles and ray lengths of corresponding reflection rays in each layer for each reflection point;
determining an updating coefficient in a seismic velocity updating model according to the imaging depth and the ray length of the corresponding reflection ray in each horizon;
and fifthly, updating the initial seismic velocity of the stratum corresponding to each reflection point by using the seismic updating model according to the updating coefficient to obtain the updated seismic velocity.
2. The method of claim 1, wherein the initial seismic velocity model for the drilled area is a seismic velocity model updated with seismic time horizon interpretation result data and real borehole log data.
3. A method as claimed in claim 1 or 2, wherein in step two, the reflection point corresponding to a next horizon is determined from the depth of a reflection point and the seismic time horizon interpretation result data and initial seismic velocity data for the next horizon of the horizon.
4. The method of claim 3, wherein the reflection points corresponding to the next horizon are determined according to the following expression:
wherein the content of the first and second substances,
seismic time horizon interpretation result data, z, representing the jth horizoniAnd zi-1Respectively representing the depth of a reflection point corresponding to the ith layer position and a reflection point corresponding to the (i-1) th layer position in the target area, viRepresenting the initial seismic velocity of the ith horizon,
representing the dip of the formation for the ith horizon.
5. The method according to any one of claims 1 to 4, wherein in the third step, for each reflection point, RMO is picked up in a common imaging point gather, and imaging depths corresponding to different reflection angles are obtained according to the RMO.
6. A method according to any one of claims 1 to 5, wherein in step three, the length of the acquired reflected rays within each horizon is the length of the rays from the reflection point to the interface between the undrilled and drilled regions.
7. The method according to any one of claims 1 to 6, wherein in step four,
determining the seismic velocity deformation corresponding to each reflection point according to the imaging depth and the ray length of the corresponding reflection ray in each horizon;
and determining an updating coefficient in a seismic velocity updating model according to the seismic velocity deformation.
8. The method according to claim 7, wherein in the fourth step, the seismic velocity deformation corresponding to each reflection point is determined according to the following expression:
wherein the content of the first and second substances,
representing the initial seismic velocity, theta, of the formation corresponding to the ith reflection point1,iAnd theta2,iTwo different reflection angles, l, respectively representing the ith reflection point1,iAnd l2,iRespectively represent the reflection angle theta1,iAnd theta2,iThe ray length of the corresponding reflected ray in the formation corresponding to the ith reflection point,
and
respectively represent the reflection angle theta1,iAnd theta2,iCorresponding imaging depth, Δ miRepresenting the deformation of the seismic velocity corresponding to the ith reflection point,
and indicating the stratum inclination angle corresponding to the ith reflection point.
9. The method of claim 8, wherein in step four, the update coefficients in the seismic velocity update model are determined according to the following expression:
wherein the content of the first and second substances,
representing the updated seismic velocity of the formation corresponding to the ith reflection point, c0,iAnd c1,iAnd indicating the updating coefficient corresponding to the ith reflection point.
10. The method of claim 9, wherein the coefficient c is updated0,iIs 1.
11. The method according to any one of claims 1 to 10, wherein in the fifth step, the initial seismic velocity of the stratum corresponding to each reflection point is updated according to the following expression:
wherein the content of the first and second substances,
representing the updated seismic velocity of the formation corresponding to the ith reflection point, c0,iAnd c1,iRepresents the updating coefficient corresponding to the ith reflection point,
and representing the initial seismic velocity of the stratum corresponding to the ith reflection point.
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