CN109143375B - Method and device for determining drilling direction - Google Patents
Method and device for determining drilling direction Download PDFInfo
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Abstract
The embodiment of the application discloses a method and a device for determining a drilling position. The method comprises the following steps: based on the vertical seismic profile velocity information, correcting the initial longitudinal migration velocity field of the first formation region in the initial depth migration velocity field to obtain a target longitudinal migration velocity field of the first formation region; correcting the initial transverse deviation velocity field of the first formation region according to well stratification data at the standard well position to obtain a target transverse deviation velocity field of the first formation region; performing prestack depth migration processing on initial seismic data according to a target longitudinal wave migration velocity field and a target transverse migration velocity field of a first stratum region and an initial longitudinal migration velocity field and an initial transverse migration velocity field of a second stratum region to obtain a target depth migration imaging result of a target work area; based on the target depth offset imaging results, a drilling position of the target well on the target layer is determined. The accuracy of the determined drilling orientation may be improved.
Description
Technical Field
The application relates to the technical field of seismic data processing, in particular to a method and a device for determining a drilling azimuth.
Background
Carbonate reservoirs are primarily composed of secondary pores, holes, and seams, and are called fracture-vug reservoirs. The high-quality reservoir usually presents 'beaded strong reflection' on a seismic section, and is a main drilling target for exploration and development of carbonate rocks at present. To accurately locate the location of a fracture-cavity reservoir and to provide a drilling azimuth for drilling, pre-stack depth migration processing of seismic data is required. Researches show that the carbonate rock fracture-cave body is very sensitive to the offset speed, and the imaging precision of the beads can be influenced by a speed error of 30-50 m generally. In early exploration and development, the target is mainly large cavern, small speed error can be tolerated, however, in new exploration, the carbonate reservoir drilling characteristics are as follows: 1. ultra-deep, often in excess of 7000 meters; 2. the target point is small, the area is about 20 meters square and round, and therefore the requirement on the accuracy of seismic data when the drilling azimuth is determined is higher, so that the drilling is carried out by utilizing the traditional depth migration result, and the risk is higher. Therefore, there is a need for an efficient method of determining a drilling orientation that improves the accuracy of the determined drilling orientation and thereby reduces the drilling risk.
Disclosure of Invention
An object of the embodiments of the present application is to provide a method and apparatus for determining a drilling orientation to improve the accuracy of the determined drilling orientation, thereby reducing the drilling risk.
To solve the above technical problem, embodiments of the present application provide a method and an apparatus for determining a drilling direction, which are implemented as follows:
a method for determining well drilling azimuth provides initial seismic data and an initial depth migration velocity field of a target work area, and vertical seismic profile velocity information at a target well location in the target work area; wherein the target well is drilled to the upper boundary of the target layer of the target work area; the method comprises the following steps:
based on the vertical seismic profile velocity information, correcting an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer;
acquiring well stratification data at the position of a standard well for the standard well which is drilled around the target well in the target work area, and correcting an initial transverse migration velocity field of a first formation region in the initial depth migration velocity field according to the well stratification data to obtain a target transverse migration velocity field of the first formation region;
performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region below the destination layer in the destination work area;
and determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
In a preferred embodiment, the performing a correction process on an initial longitudinal offset velocity field of a first formation region in the initial depth offset velocity field includes:
picking seismic profile horizons of a plurality of strata of the first stratum region from the initial seismic data in a mode of same-phase axis tracking;
acquiring initial longitudinal migration velocity of the drilling position of the target well in the seismic profile horizon from an initial longitudinal migration velocity field of the first stratum region, acquiring vertical seismic profile velocity of the drilling position of the target well in the seismic profile horizon from the vertical seismic profile velocity information, and determining a longitudinal correction coefficient corresponding to the seismic profile horizon based on the initial longitudinal migration velocity of the drilling position of the target well in the seismic profile horizon and the vertical seismic profile velocity;
taking the product of the longitudinal correction coefficient corresponding to the seismic profile horizon and the initial longitudinal migration velocity at each sampling point position on the seismic profile horizon as the target longitudinal migration velocity at each sampling point position on the seismic profile horizon;
and determining a target longitudinal migration velocity field of the first stratum region according to the determined target longitudinal migration velocity at the position of the sampling point on each seismic profile horizon.
In a preferred embodiment, determining the longitudinal correction coefficient corresponding to the seismic profile horizon includes:
and taking the ratio of the average value of the initial longitudinal migration velocity at the drilling position of the target well in the seismic profile horizon to the average value of the vertical seismic profile velocity as a longitudinal correction coefficient corresponding to the seismic profile horizon.
In a preferred embodiment, the performing a correction process on an initial lateral offset velocity field of a first formation region in the initial depth offset velocity field includes:
for a specified stratum in a plurality of strata of a first stratum area, obtaining a well level at the standard well drilling position in the specified stratum from the well layer data, and obtaining a seismic profile level at the standard well drilling position in the specified stratum from the picked seismic profile levels of the plurality of strata of the first stratum area; the ratio of the absolute value of the difference value between the logging data values of two adjacent logging points in the logging data of the specified stratum to the average value of the logging data values of all the logging points of the specified stratum is smaller than or equal to a prediction proportion threshold value;
determining a horizontal scale factor corresponding to each sampling point in the specified stratum according to the well horizon and the seismic profile horizon at the standard well drilling position in the specified stratum;
determining a transverse scale factor corresponding to each sampling point in the first stratum region according to the transverse scale factor corresponding to each sampling point in the specified stratum;
and correcting the initial transverse deviation speed field of the first formation region based on the transverse scale factors corresponding to the sampling points in the first formation region to obtain a target transverse deviation speed field of the first formation region.
In a preferred embodiment, determining the lateral scaling factor corresponding to each sampling point in the specified formation includes:
when the absolute value of the depth difference value between the well horizon and the seismic profile horizon at the standard well drilling position in the specified stratum is less than or equal to a preset depth threshold value, determining that the transverse scale factor at the standard well drilling position in the specified stratum is 1;
when the absolute value of the depth difference between the well horizon at the standard well drilling position in the specified stratum and the seismic profile horizon is larger than a preset depth threshold, taking the ratio of the absolute value of the depth difference to the distance from the well horizon at the standard well drilling position in the specified stratum to the ground surface as a transverse scaling factor at the standard well drilling position in the specified stratum;
and determining the transverse scaling factor corresponding to each sampling point in the specified stratum in an interpolation mode based on the transverse scaling factor at the standard well drilling position in the specified stratum.
Preferably, the correcting the initial lateral offset velocity field of the first formation region includes:
when the transverse scale factor corresponding to the specified sampling point in the first stratum region is 1, taking the transverse scale factor corresponding to the specified sampling point as a transverse correction coefficient corresponding to the specified sampling point;
when the transverse scale factor corresponding to the specified sampling point in the first stratum region is not 1, adding 1 to the transverse scale factor corresponding to the specified sampling point to serve as a transverse correction coefficient corresponding to the specified sampling point;
taking the product of the transverse correction coefficient corresponding to the specified sampling point and the initial transverse offset speed at the specified sampling point position as the target transverse offset speed at the specified sampling point position;
and determining a target transverse offset velocity field of the first formation region according to the determined target transverse offset velocity at the sampling point position in the first formation region.
In a preferred embodiment, before the pre-stack depth migration processing is performed on the initial seismic data, the method further includes:
for a first designated area with the coverage times smaller than the designated coverage times in the target work area, based on the coverage times of the first designated area, performing correction processing on the initial seismic subdata of the first designated area in the initial seismic data to obtain target seismic subdata of the first designated area;
determining target seismic data of the target work area according to the target seismic subdata of the first designated area and the initial seismic subdata of a second designated area in the initial seismic data; the second designated area represents an area, in the target work area, of which the covering times are greater than or equal to the designated covering times;
accordingly, performing pre-stack depth migration processing on the initial seismic data, comprising: and carrying out prestack depth migration processing on the target seismic data.
In a preferred embodiment, the modifying the initial seismic sub-data of the first designated area in the initial seismic data includes:
dividing the initial amplitude value of a designated sampling point in the initial seismic subdata of the first designated area by the square root of the covering times at the position of the designated sampling point to obtain a target amplitude value of the designated sampling point;
and determining the target earthquake subdata of the first designated area according to the determined target amplitude values of the sampling points in the first designated area.
An apparatus for determining a borehole azimuth, the apparatus providing initial seismic data and an initial depth migration velocity field for a target work zone, and vertical seismic profile velocity information at a target well location in the target work zone; wherein the target well is drilled to the upper boundary of the target layer of the target work area; the device comprises: the system comprises a target longitudinal offset velocity field determining module, a target transverse offset velocity field determining module, an offset imaging result determining module and a drilling azimuth determining module; wherein,
the target longitudinal migration velocity field determining module is used for correcting the initial longitudinal migration velocity field of the first formation region in the initial depth migration velocity field based on the vertical seismic profile velocity information to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer;
the target lateral deviation velocity field determining module is configured to obtain well stratification data at a position of a standard well for a standard well in the target work area, the standard well being drilled around the target well, and correct an initial lateral deviation velocity field of a first formation region in the initial depth deviation velocity field according to the well stratification data to obtain a target lateral deviation velocity field of the first formation region;
the migration imaging result determining module is configured to perform prestack depth migration processing on the initial seismic data according to a target longitudinal migration velocity field and a target lateral migration velocity field of the first formation region and an initial longitudinal migration velocity field and an initial lateral migration velocity field of a second formation region in the initial depth migration velocity field, so as to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region below the destination layer in the destination work area;
and the drilling position determining module is used for determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
An apparatus for determining a well bore orientation, comprising a memory, a processor, and a computer program stored on the memory, the memory storing initial seismic data and an initial depth-offset velocity field for a destination work zone, and vertical seismic profile velocity information at a target well location in the destination work zone; wherein the target well is drilled to the upper boundary of the target layer of the target work area; the computer program when executed by the processor performs the steps of:
based on the vertical seismic profile velocity information, correcting an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer;
acquiring well stratification data at the position of a standard well for the standard well which is drilled around the target well in the target work area, and correcting an initial transverse migration velocity field of a first formation region in the initial depth migration velocity field according to the well stratification data to obtain a target transverse migration velocity field of the first formation region;
performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region below the destination layer in the destination work area;
and determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
According to the technical scheme provided by the embodiment of the application, firstly, the method and the device for determining the drilling azimuth provided by the embodiment of the application can correct the initial longitudinal migration velocity field of the first formation region in the initial depth migration velocity field based on the vertical seismic profile velocity information to obtain the target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer. Then, for a standard well which is located around the target well in the target work area and has been drilled, well stratification data at the position of the standard well may be obtained, and according to the well stratification data, an initial lateral migration velocity field of a first formation region in the initial depth migration velocity field may be corrected, so as to obtain a target lateral migration velocity field of the first formation region. Then, performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region located below the destination layer in the destination work area. Finally, a drilling position of the target well on the target layer can be determined based on the target depth offset imaging result. Therefore, the drilling position of the target well on the target layer is guided through the determined target depth offset imaging result with higher precision, the accuracy of the determined drilling position can be improved, and the drilling risk is reduced.
Drawings
In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort.
FIG. 1 is a flow chart of an embodiment of a method of determining a drilling orientation of the present application;
FIG. 2 is a schematic illustration of the individual seismic profile horizon longitudinal correction coefficients in a first formation region determined in an embodiment of the present application;
FIG. 3 is a schematic illustration of a seismic profile showing well stratification data for a standard well surrounding a target well in an embodiment of the present application;
FIG. 4 is a schematic diagram of an embodiment of the apparatus for determining a borehole azimuth of the present application;
FIG. 5 is a schematic diagram of the components of another embodiment of the apparatus for determining a borehole azimuth of the present application.
Detailed Description
The embodiment of the application provides a method and a device for determining a drilling direction.
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application.
A method of determining a drilling orientation is provided. The method for determining the well drilling azimuth can provide initial seismic data and an initial depth migration velocity field of a target work area and vertical seismic profile velocity information at a target well position in the target work area; wherein the target well is drilled to a target layer upper boundary of the target work area.
In this embodiment, the target work area may be a work area yet to be developed or being developed, such as a middle area of a Tarim basin tower. The target well position in the target work area may refer to a position where Vertical Seismic Profile (VSP) velocity information can be detected through a well being drilled in the target work area. Wherein the target well is drilled from the surface to an upper boundary of a target layer of the target work area, the target layer not yet being drilled.
In this embodiment, the destination layer may refer to a reservoir in which the drilling position has not been determined. The reservoir may be, for example, a fracture-cavity reservoir. The depth of the destination layer is typically deep, for example, the depth of the destination layer may exceed 7000 meters.
In this embodiment, the initial seismic data and the initial depth migration velocity field of the target work area may be obtained in a seismic exploration mode and a data acquisition mode. The initial depth offset velocity field may include an initial longitudinal offset velocity field and an initial lateral offset velocity field. Wherein, the horizontal direction and the longitudinal direction are respectively the horizontal direction and the direction vertical to the horizontal direction.
FIG. 1 is a flow chart of an embodiment of a method of determining a drilling orientation of the present application. As shown in FIG. 1, the method for determining the well drilling position comprises the following steps.
Step S101: based on the vertical seismic profile velocity information, correcting an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer.
In this embodiment, based on the vertical seismic profile velocity information, an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field may be corrected to obtain a target longitudinal migration velocity field of the first formation region. Wherein the first formation region represents a formation region of the destination work zone that is above the destination layer. Specifically, seismic profile horizons of multiple strata of the first formation region may first be picked from the initial seismic data using in-phase axis tracking. Then, an initial longitudinal migration velocity at the drilling position of the target well in the seismic profile horizon and a vertical seismic profile velocity at the drilling position of the target well in the seismic profile horizon from the initial longitudinal migration velocity field of the first formation region may be obtained, and a longitudinal correction coefficient corresponding to the seismic profile horizon may be determined based on the initial longitudinal migration velocity and the vertical seismic profile velocity at the drilling position of the target well in the seismic profile horizon. Then, the product of the longitudinal correction coefficient corresponding to the seismic profile horizon and the initial longitudinal migration velocity at each sampling point position on the seismic profile horizon can be used as the target longitudinal migration velocity at each sampling point position on the seismic profile horizon. Finally, a target longitudinal migration velocity field of the first formation region may be determined according to the determined target longitudinal migration velocity at the position of the sampling point on each seismic profile horizon.
In this embodiment, the picking up the seismic section horizons of the multiple strata in the first stratum region from the initial seismic data by using a method of event-axis tracking may specifically include comparing waveform characteristics corresponding to two adjacent seismic channel data in the initial seismic data within a specified time window, and picking up the seismic section horizons of the multiple strata in the first stratum region according to similarity of the waveform characteristics. The seismic profile horizon may be used to characterize the depth of the formations of the different strata in the first stratum region on the seismic profile characterized by the initial seismic data.
In this embodiment, the determining the longitudinal correction coefficient corresponding to the seismic profile horizon based on the initial longitudinal migration velocity and the vertical seismic profile velocity at the drilling position of the target well in the seismic profile horizon may specifically include taking a ratio of an average value of the initial longitudinal migration velocity and an average value of the vertical seismic profile velocity at the drilling position of the target well in the seismic profile horizon as the longitudinal correction coefficient corresponding to the seismic profile horizon. Wherein the longitudinal correction coefficients corresponding to the respective sampling points at the seismic profile horizon may be the same. The sampling points may refer to sampling points in the initial seismic data. For example, FIG. 2 is a schematic illustration of the individual seismic profile horizon longitudinal correction coefficients in the first formation region determined in an embodiment of the present application. The abscissa and ordinate in fig. 2 are the seismic trace number and correction coefficient, respectively.
Step S102: and acquiring well stratification data at the position of the standard well aiming at the standard well which is positioned around the target well and drilled in the target work area, and correcting the initial transverse migration velocity field of a first formation region in the initial depth migration velocity field according to the well stratification data to obtain the target transverse migration velocity field of the first formation region.
In this embodiment, well-stratification data at the standard well location may be obtained for a standard well in the target work area that has been drilled around the target well.
In this embodiment, according to the well stratification data, an initial lateral migration velocity field of a first formation region in the initial depth migration velocity field may be corrected to obtain a target lateral migration velocity field of the first formation region, and specifically, for a specified formation in a plurality of formations of the first formation region, a well horizon at the standard well drilling position in the specified formation may be obtained from the well stratification data. For example, FIG. 3 is a schematic illustration of a seismic profile showing well stratification data for a standard well surrounding a target well in an embodiment of the present application. The abscissa and ordinate in fig. 3 are the seismic trace number and the sampling time, respectively, wherein the unit of the sampling time is milliseconds. As shown in FIG. 3, the standard wells surrounding the target well may be, for example, those of ZG7-5, ZG702, ZG7, TZ and ZG512, in which the formation TC corresponds TO well levels of TC-TC3069, TC-TC3053, TC-TC3035, TC-TC2966 and TC-TC3025, respectively, and the formation TO3s corresponds TO well levels of TO3s-TO3s4261, TO3s-TO3s4168, TO3s-TO3s4149, TO3s-TO3s3776 and TO3s-TO3s3715, respectively. Seismic profile horizons at the standard well encounter location in the specified formation may be obtained from the picked seismic profile horizons of the plurality of formations of the first formation region. And the ratio of the absolute value of the difference value between the logging data values of two adjacent logging points in the logging data of the specified stratum to the average value of the logging data values of all the logging points of the specified stratum is less than or equal to a prediction proportion threshold value. The logging data may specifically be resistivity logging data, density logging data, or the like. Accordingly, the well log data values may be resistivity values, densities, and the like. The value range of the prediction proportion threshold value can be 0-0.2, specifically, the value range can be set according to the actual logging condition, and the value range is not limited here. Then, according to the well horizon and the seismic profile horizon at the standard well drilling position in the specified stratum, determining a transverse scaling factor corresponding to each sampling point in the specified stratum. Then, according to the horizontal scale factor corresponding to each sampling point in the designated stratum, the horizontal scale factor corresponding to each sampling point in the first stratum region may be determined. Finally, the initial lateral deviation velocity field of the first formation region may be corrected based on the lateral scale factor corresponding to each sampling point in the first formation region, so as to obtain a target lateral deviation velocity field of the first formation region.
In this embodiment, determining the lateral scaling factor corresponding to each sampling point in the specified stratum according to the well horizon and the seismic profile horizon at the standard well drilling position in the specified stratum may specifically include determining that the lateral scaling factor at the standard well drilling position in the specified stratum is 1 when an absolute value of a depth difference between the well horizon and the seismic profile horizon at the standard well drilling position in the specified stratum is less than or equal to a preset depth threshold. When the absolute value of the depth difference between the well horizon at the standard well drilling position in the specified stratum and the seismic profile horizon is greater than a preset depth threshold, the ratio of the absolute value of the depth difference to the distance from the well horizon at the standard well drilling position in the specified stratum to the ground surface may be used as the lateral scaling factor at the standard well drilling position in the specified stratum. And determining the transverse scaling factor corresponding to each sampling point in the specified stratum in an interpolation mode based on the transverse scaling factor at the standard well drilling position in the specified stratum. For example, the horizontal scale factors corresponding to the other sampling points in the specified stratum except the sampling point at the standard well drilling position can be determined by adopting an inverse distance weighted interpolation mode based on the horizontal scale factors at the standard well drilling position in the specified stratum.
In this embodiment, determining the horizontal scaling factor corresponding to each sampling point in the first formation region according to the horizontal scaling factor corresponding to each sampling point in the designated formation may specifically include taking the horizontal scaling factor corresponding to one sampling point in the designated formation as the horizontal scaling factor corresponding to each sampling point having the same horizontal position as the sampling point in other formations in the first formation region. Wherein the other formations may represent formations in the first formation region other than the designated formation. In this way, the lateral scale factor corresponding to each sampling point in the first formation region may be determined.
In this embodiment, the correcting the initial lateral migration velocity field of the first formation region based on the lateral scaling factor corresponding to each sampling point in the first formation region to obtain the target lateral migration velocity field of the first formation region may specifically include, when the lateral scaling factor corresponding to the designated sampling point in the first formation region is 1, using the lateral scaling factor corresponding to the designated sampling point as the lateral correction coefficient corresponding to the designated sampling point. When the transverse scale factor corresponding to the designated sampling point in the first formation region is not 1, adding 1 to the transverse scale factor corresponding to the designated sampling point to serve as the transverse correction coefficient corresponding to the designated sampling point. Then, the product of the lateral correction coefficient corresponding to the specified sampling point and the initial lateral offset speed at the specified sampling point position can be used as the target lateral offset speed at the specified sampling point position. Finally, a target lateral offset velocity field of the first formation region may be determined based on the determined target lateral offset velocity at each sampling point location in the first formation region.
Step S103: performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region located below the destination layer in the destination work area.
In this embodiment, according to the target longitudinal migration velocity field and the target lateral migration velocity field of the first formation region, and the initial longitudinal migration velocity field and the target lateral migration velocity field of the second formation region in the initial depth migration velocity field, the pre-stack depth migration processing may be performed on the initial seismic data, so as to obtain the target depth migration imaging result of the target work area. Wherein the second formation region represents the destination layer and a formation region located below the destination layer in the destination work area. Specifically, first, the target offset velocity field of the target work area may be determined according to the target longitudinal offset velocity field and the target lateral offset velocity field of the first formation region, and the initial longitudinal offset velocity field and the initial lateral offset velocity field of the second formation region in the initial depth offset velocity field. Then, according to the target migration velocity field, pre-stack depth migration processing can be performed on the initial seismic data, and a target depth migration imaging result of the target work area can be obtained. Wherein the location of the fracture-hole body in the destination layer can be identified from the target depth offset imaging result.
Step S104: and determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
In this embodiment, determining the drilling position of the target well on the target layer based on the target depth offset imaging result may specifically include identifying the position of the fracture-cavity body in the target layer from the target depth offset imaging result. For example, the identification can be carried out according to the beaded strong reflection characteristics of the fracture-cavity body in the target depth offset imaging result. After the locations of the fracture-cavity bodies in the target layer are identified, a drilling position of the target well on the target layer can be determined according to the location of the target well drilled to the boundary on the target layer and the locations of the fracture-cavity bodies in the target layer.
In an embodiment of the application, in order to avoid a position migration of a fracture-cavity body caused by the target well being located in a less-than-coverage area of the target work area, where the less-than-coverage area may represent an area with a coverage frequency less than a specified coverage frequency in the target work area, before performing prestack depth migration processing on the initial seismic data, the method may further include, for a first specified area with a coverage frequency less than the specified coverage frequency in the target work area, performing correction processing on the initial seismic sub-data of the first specified area in the initial seismic data based on the coverage frequency of the first specified area, and obtaining target seismic sub-data of the first specified area. Then, determining target seismic data of the target work area according to the target seismic subdata of the first designated area and the initial seismic subdata of a second designated area in the initial seismic data; and the second designated area represents an area in the target work area, wherein the number of times of coverage is greater than or equal to the designated number of times of coverage. Correspondingly, the pre-stack depth migration processing may be performed on the initial seismic data, and specifically, the pre-stack depth migration processing may be performed on the target seismic data. In this embodiment, the specified number of coverage times may specifically be the number of coverage times that the observation system is designed to cover during the seismic exploration.
In this embodiment, the modifying the initial seismic sub-data of the first designated area in the initial seismic data based on the number of times of coverage of the first designated area to obtain the target seismic sub-data of the first designated area may specifically include dividing an initial amplitude value of a designated sampling point in the initial seismic sub-data of the first designated area by a square root of the number of times of coverage at the position of the designated sampling point to obtain a target amplitude value of the designated sampling point. The designated sampling point can represent any sampling point in the initial seismic subdata. The target seismic subdata of the first designated area may be determined according to the determined target amplitude values of the sampling points in the first designated area.
According to the method for determining the well drilling azimuth, firstly, an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field can be corrected based on the vertical seismic profile velocity information, so that a target longitudinal migration velocity field of the first formation region is obtained; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer. Then, for a standard well which is located around the target well in the target work area and has been drilled, well stratification data at the position of the standard well may be obtained, and according to the well stratification data, an initial lateral migration velocity field of a first formation region in the initial depth migration velocity field may be corrected, so as to obtain a target lateral migration velocity field of the first formation region. Then, performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region located below the destination layer in the destination work area. Finally, a drilling position of the target well on the target layer can be determined based on the target depth offset imaging result. Therefore, the drilling position of the target well on the target layer is guided through the determined target depth offset imaging result with higher precision, the accuracy of the determined drilling position can be improved, and the drilling risk is reduced.
FIG. 4 is a schematic diagram of the components of an embodiment of the apparatus for determining a borehole azimuth of the present application. The device for determining the well drilling azimuth can provide initial seismic data and an initial depth migration velocity field of a target work area and vertical seismic profile velocity information at a target well position in the target work area; wherein the target well is drilled to a target layer upper boundary of the target work area. As shown in fig. 4, the means for determining the orientation of the borehole may comprise: a target longitudinal offset velocity field determination module 100, a target lateral offset velocity field determination module 200, an offset imaging result determination module 300, and a drilling azimuth determination module 400.
The target longitudinal migration velocity field determining module 100 may be configured to correct an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field based on the vertical seismic profile velocity information, so as to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer.
The target lateral offset velocity field determining module 200 may be configured to, for a standard well in the target work area, which is located around the target well and has been drilled, obtain well-level data at a position of the standard well, and correct an initial lateral offset velocity field of a first formation region in the initial depth offset velocity field according to the well-level data, so as to obtain a target lateral offset velocity field of the first formation region.
The migration imaging result determining module 300 may be configured to perform prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target lateral migration velocity field of the first formation region, and the initial longitudinal migration velocity field and the initial lateral migration velocity field of the second formation region in the initial depth migration velocity field, so as to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region located below the destination layer in the destination work area.
The drilling position determination module 400 may be configured to determine a drilling position of the target well on the target layer based on the target depth offset imaging result.
FIG. 5 is a schematic diagram of the components of another embodiment of the apparatus for determining a borehole azimuth of the present application. As shown in fig. 5, the apparatus for determining a borehole azimuth may include a memory, a processor, and a computer program stored on the memory, the memory storing initial seismic data and an initial depth-offset velocity field for a destination worksite, and vertical seismic profile velocity information at a target well location in the destination worksite; wherein the target well is drilled to the upper boundary of the target layer of the target work area; the computer program when executed by the processor performs the steps of:
step S101: based on the vertical seismic profile velocity information, correcting an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer;
step S102: acquiring well stratification data at the position of a standard well for the standard well which is drilled around the target well in the target work area, and correcting an initial transverse migration velocity field of a first formation region in the initial depth migration velocity field according to the well stratification data to obtain a target transverse migration velocity field of the first formation region;
step S103: performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region below the destination layer in the destination work area;
step S104: and determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
The embodiment of the device for determining the drilling orientation corresponds to the embodiment of the method for determining the drilling orientation, so that the technical scheme of the embodiment of the method for determining the drilling orientation can be realized, and the technical effect of the embodiment of the method can be obtained.
In the 90 s of the 20 th century, improvements in a technology could clearly distinguish between improvements in hardware (e.g., improvements in circuit structures such as diodes, transistors, switches, etc.) and improvements in software (improvements in process flow). However, as technology advances, many of today's process flow improvements have been seen as direct improvements in hardware circuit architecture. Designers almost always obtain the corresponding hardware circuit structure by programming an improved method flow into the hardware circuit. Thus, it cannot be said that an improvement in the process flow cannot be realized by hardware physical modules. For example, a Programmable Logic Device (PLD), such as a Field Programmable Gate Array (FPGA), is an integrated circuit whose Logic functions are determined by programming the Device by a user. A digital system is "integrated" on a PLD by the designer's own programming without requiring the chip manufacturer to design and fabricate application-specific integrated circuit chips. Furthermore, nowadays, instead of manually making an integrated Circuit chip, such Programming is often implemented by "logic compiler" software, which is similar to a software compiler used in program development and writing, but the original code before compiling is also written by a specific Programming Language, which is called Hardware Description Language (HDL), and HDL is not only one but many, such as abel (advanced Boolean Expression Language), ahdl (alternate Language Description Language), traffic, pl (core unified Programming Language), HDCal, JHDL (Java Hardware Description Language), langue, Lola, HDL, laspam, hardsradware (Hardware Description Language), vhjhd (Hardware Description Language), and vhigh-Language, which are currently used in most common. It will also be apparent to those skilled in the art that hardware circuitry that implements the logical method flows can be readily obtained by merely slightly programming the method flows into an integrated circuit using the hardware description languages described above.
Those skilled in the art will also appreciate that, in addition to implementing the controller as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such a controller may thus be considered a hardware component, and the means included therein for performing the various functions may also be considered as a structure within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
The apparatuses and modules illustrated in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions.
For convenience of description, the above devices are described as being divided into various modules by functions, and are described separately. Of course, the functionality of the various modules may be implemented in the same one or more software and/or hardware implementations as the present application.
From the above description of the embodiments, it is clear to those skilled in the art that the present application can be implemented by software plus necessary general hardware platform. With this understanding in mind, the present solution, or portions thereof that contribute to the prior art, may be embodied in the form of a software product, which in a typical configuration includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory. The computer software product may include instructions for causing a computing device (which may be a personal computer, a server, or a network device, etc.) to perform the methods described in the various embodiments or portions of embodiments of the present application. The computer software product may be stored in a memory, which may include forms of volatile memory in a computer readable medium, Random Access Memory (RAM) and/or non-volatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM). Memory is an example of a computer-readable medium. Computer-readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), Static Random Access Memory (SRAM), Dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), Read Only Memory (ROM), Electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), Digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium that can be used to store information that can be accessed by a computing device. As defined herein, computer readable media does not include transitory computer readable media (transient media), such as modulated data signals and carrier waves.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, as for the apparatus embodiment, since it is substantially similar to the method embodiment, the description is relatively simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The application is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable consumer electronics, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
While the present application has been described with examples, those of ordinary skill in the art will appreciate that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the spirit of the application.
Claims (10)
1. A method of determining well placement, wherein initial seismic data and an initial depth migration velocity field are provided for a target work zone, and vertical seismic profile velocity information is provided at a target well location in the target work zone; wherein the target well is drilled to the upper boundary of the target layer of the target work area; the method comprises the following steps:
based on the vertical seismic profile velocity information, correcting an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer;
acquiring well stratification data at the position of a standard well for the standard well which is drilled around the target well in the target work area, and correcting an initial transverse migration velocity field of a first formation region in the initial depth migration velocity field according to the well stratification data to obtain a target transverse migration velocity field of the first formation region;
performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region below the destination layer in the destination work area;
and determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
2. The method of claim 1, wherein performing a correction process on an initial longitudinal offset velocity field of a first formation region in the initial depth offset velocity field comprises:
picking seismic profile horizons of a plurality of strata of the first stratum region from the initial seismic data in a mode of same-phase axis tracking;
acquiring initial longitudinal migration velocity of the drilling position of the target well in the seismic profile horizon from an initial longitudinal migration velocity field of the first stratum region, acquiring vertical seismic profile velocity of the drilling position of the target well in the seismic profile horizon from the vertical seismic profile velocity information, and determining a longitudinal correction coefficient corresponding to the seismic profile horizon based on the initial longitudinal migration velocity of the drilling position of the target well in the seismic profile horizon and the vertical seismic profile velocity;
taking the product of the longitudinal correction coefficient corresponding to the seismic profile horizon and the initial longitudinal migration velocity at each sampling point position on the seismic profile horizon as the target longitudinal migration velocity at each sampling point position on the seismic profile horizon;
and determining a target longitudinal migration velocity field of the first stratum region according to the determined target longitudinal migration velocity at the position of the sampling point on each seismic profile horizon.
3. The method of claim 2, wherein determining the longitudinal correction coefficients corresponding to the seismic profile horizons comprises:
and taking the ratio of the average value of the initial longitudinal migration velocity at the drilling position of the target well in the seismic profile horizon to the average value of the vertical seismic profile velocity as a longitudinal correction coefficient corresponding to the seismic profile horizon.
4. The method of claim 2, wherein performing a correction process on an initial lateral offset velocity field for a first formation region in the initial depth offset velocity field comprises:
for a specified stratum in a plurality of strata of a first stratum area, obtaining a well level at the standard well drilling position in the specified stratum from the well layer data, and obtaining a seismic profile level at the standard well drilling position in the specified stratum from the picked seismic profile levels of the plurality of strata of the first stratum area; the ratio of the absolute value of the difference value between the logging data values of two adjacent logging points in the logging data of the specified stratum to the average value of the logging data values of all the logging points of the specified stratum is smaller than or equal to a prediction proportion threshold value;
determining a horizontal scale factor corresponding to each sampling point in the specified stratum according to the well horizon and the seismic profile horizon at the standard well drilling position in the specified stratum;
determining a transverse scale factor corresponding to each sampling point in the first stratum region according to the transverse scale factor corresponding to each sampling point in the specified stratum;
and correcting the initial transverse deviation speed field of the first formation region based on the transverse scale factors corresponding to the sampling points in the first formation region to obtain a target transverse deviation speed field of the first formation region.
5. The method of claim 4, wherein determining the lateral scaling factor corresponding to each sampling point in the specified formation comprises:
when the absolute value of the depth difference value between the well horizon and the seismic profile horizon at the standard well drilling position in the specified stratum is less than or equal to a preset depth threshold value, determining that the transverse scale factor at the standard well drilling position in the specified stratum is 1;
when the absolute value of the depth difference between the well horizon at the standard well drilling position in the specified stratum and the seismic profile horizon is larger than a preset depth threshold, taking the ratio of the absolute value of the depth difference to the distance from the well horizon at the standard well drilling position in the specified stratum to the ground surface as a transverse scaling factor at the standard well drilling position in the specified stratum;
and determining the transverse scaling factor corresponding to each sampling point in the specified stratum in an interpolation mode based on the transverse scaling factor at the standard well drilling position in the specified stratum.
6. The method of claim 4, wherein performing a corrective action on the initial lateral offset velocity field of the first formation region comprises:
when the transverse scale factor corresponding to the specified sampling point in the first stratum region is 1, taking the transverse scale factor corresponding to the specified sampling point as a transverse correction coefficient corresponding to the specified sampling point;
when the transverse scale factor corresponding to the specified sampling point in the first stratum region is not 1, adding 1 to the transverse scale factor corresponding to the specified sampling point to serve as a transverse correction coefficient corresponding to the specified sampling point;
taking the product of the transverse correction coefficient corresponding to the specified sampling point and the initial transverse offset speed at the specified sampling point position as the target transverse offset speed at the specified sampling point position;
and determining a target transverse offset velocity field of the first formation region according to the determined target transverse offset velocity at the sampling point position in the first formation region.
7. The method of claim 1, wherein prior to the pre-stack depth migration processing of the initial seismic data, the method further comprises:
for a first designated area with the coverage times smaller than the designated coverage times in the target work area, based on the coverage times of the first designated area, performing correction processing on the initial seismic subdata of the first designated area in the initial seismic data to obtain target seismic subdata of the first designated area;
determining target seismic data of the target work area according to the target seismic subdata of the first designated area and the initial seismic subdata of a second designated area in the initial seismic data; the second designated area represents an area, in the target work area, of which the covering times are greater than or equal to the designated covering times;
accordingly, performing pre-stack depth migration processing on the initial seismic data, comprising: and carrying out prestack depth migration processing on the target seismic data.
8. The method of claim 7, wherein modifying the initial seismic sub-data for the first designated area in the initial seismic data comprises:
dividing the initial amplitude value of a designated sampling point in the initial seismic subdata of the first designated area by the square root of the covering times at the position of the designated sampling point to obtain a target amplitude value of the designated sampling point;
and determining the target earthquake subdata of the first designated area according to the determined target amplitude values of the sampling points in the first designated area.
9. An apparatus for determining a borehole azimuth, the apparatus providing initial seismic data and an initial depth migration velocity field for a target work zone, and vertical seismic profile velocity information at a target well location in the target work zone; wherein the target well is drilled to the upper boundary of the target layer of the target work area; the device comprises: the system comprises a target longitudinal offset velocity field determining module, a target transverse offset velocity field determining module, an offset imaging result determining module and a drilling azimuth determining module; wherein,
the target longitudinal migration velocity field determining module is used for correcting the initial longitudinal migration velocity field of the first formation region in the initial depth migration velocity field based on the vertical seismic profile velocity information to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer;
the target lateral deviation velocity field determining module is configured to obtain well stratification data at a position of a standard well for a standard well in the target work area, the standard well being drilled around the target well, and correct an initial lateral deviation velocity field of a first formation region in the initial depth deviation velocity field according to the well stratification data to obtain a target lateral deviation velocity field of the first formation region;
the migration imaging result determining module is configured to perform prestack depth migration processing on the initial seismic data according to a target longitudinal migration velocity field and a target lateral migration velocity field of the first formation region and an initial longitudinal migration velocity field and an initial lateral migration velocity field of a second formation region in the initial depth migration velocity field, so as to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region below the destination layer in the destination work area;
and the drilling position determining module is used for determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
10. An apparatus for determining a well bore orientation, comprising a memory, a processor, and a computer program stored on the memory, wherein the memory stores initial seismic data and an initial depth-offset velocity field for a destination worksite, and vertical seismic profile velocity information at a target well location in the destination worksite; wherein the target well is drilled to the upper boundary of the target layer of the target work area; the computer program when executed by the processor performs the steps of:
based on the vertical seismic profile velocity information, correcting an initial longitudinal migration velocity field of a first formation region in the initial depth migration velocity field to obtain a target longitudinal migration velocity field of the first formation region; wherein the first formation region represents a formation region of the destination work zone that is above the destination layer;
acquiring well stratification data at the position of a standard well for the standard well which is drilled around the target well in the target work area, and correcting an initial transverse migration velocity field of a first formation region in the initial depth migration velocity field according to the well stratification data to obtain a target transverse migration velocity field of the first formation region;
performing prestack depth migration processing on the initial seismic data according to the target longitudinal migration velocity field and the target transverse migration velocity field of the first formation region and the initial longitudinal migration velocity field and the initial transverse migration velocity field of the second formation region in the initial depth migration velocity field to obtain a target depth migration imaging result of the target work area; wherein the second formation region represents the destination layer and a formation region below the destination layer in the destination work area;
and determining the drilling position of the target well on the target layer based on the target depth offset imaging result.
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| CN112083484A (en) * | 2019-06-12 | 2020-12-15 | 中国石油天然气集团有限公司 | Method and device for detecting true thickness of stratum |
| CN112433247B (en) * | 2020-11-17 | 2022-09-02 | 中国石油化工股份有限公司 | While-drilling adjusting method and device for position of stratum to be drilled |
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