A method and device for calculating a dip angle of a combined longitudinal and transverse wave formation

Abstract

This application provides a method for calculating formation dip angle using combined P-wave and S-wave data, belonging to the field of seismic exploration acquisition, processing, and interpretation. The calculation method involves exciting seismic waves at a predetermined point at the wellhead in the target area, and receiving the resulting wellbore seismic data through a geophone installed at the wellhead. First P-wave and first S-wave data are preprocessed to obtain second P-wave and second S-wave data. The first arrival waves of the second P-wave and the first arrival waves of the second S-wave are acquired. Based on the first arrival waves of the P-wave and S-wave, a first calculation depth is determined. Based on the first arrival waves of the P-wave and S-wave, a second and third calculation depths above the target formation location are determined. Second and third time data are acquired. Based on the second and third time data, the dip angle of the target formation corresponding to the wellhead in the target area is determined. This application aims to improve the accuracy of formation dip angle calculation.

Description

Technical Field

[0001] This application relates to the field of seismic exploration acquisition, processing and interpretation, and more specifically, to a method and apparatus for calculating the dip angle of strata using combined P-wave and S-wave signals. Background Technology

[0002] The detection and prediction of stratigraphic dip angle has long been a challenge in the field of geophysics. Accurate calculation of stratigraphic dip angle is crucial for determining geological structures and estimating oil and gas reserves, and has been an important goal pursued by geophysicists at home and abroad for many years.

[0003] Currently, there are two main categories of methods for calculating dip angles using geophysical data: The first category uses well logging methods. For example, some researchers, when calculating the dip angle and azimuth of formations, first compare four, six, or eight microresistivity curves to determine the elevation difference between corresponding points on each curve. The method involves fixing a depth segment on one curve, moving a second curve, calculating the correlation coefficient of the second curve at various locations, and identifying the point with the highest correlation coefficient. This point represents the best point for comparison between the two curve segments, thus allowing the determination of the formation dip angle.

[0004] The second type of method uses seismic methods for calculation. For example, some scholars determine the similar energy spectrum of each preset scanning dip angle based on seismic waveform data and the seismic waveform data of adjacent traces corresponding to each preset scanning dip angle. The step of determining the stratum dip angle is to extract the maximum similar energy spectrum from each similar energy spectrum and take the preset scanning dip angle corresponding to the maximum similar energy spectrum as the stratum dip angle.

[0005] However, the above method has insufficient accuracy in calculating the dip angle of the strata when faced with problems such as the large calculation error due to the close approximate apparent velocity of the P-waves in steep tectonic strata, the weak development of the S-waves in gentle strata, and more complex strata. Summary of the Invention

[0006] This application provides a method and apparatus for calculating the dip angle of formations using combined P-wave and S-wave measurements, aiming to improve the accuracy of formation dip angle calculation.

[0007] In a first aspect, embodiments of this application provide a method for calculating the dip angle of formations using combined P-wave and S-wave propagation, comprising the following steps:

[0008] Seismic waves are emitted from a preset point at the wellhead in the target area, and the well seismic data generated by the seismic waves is received by a detector installed in the wellhead. The well seismic data includes first P-wave data and first S-wave data.

[0009] The first longitudinal wave data and the first transverse wave data are preprocessed to obtain the second longitudinal wave data and the second transverse wave data.

[0010] Pick up the first arrival of the P-wave from the second P-wave data and the first arrival of the S-wave from the second S-wave data respectively;

[0011] Based on the first arrival of the longitudinal wave and the first arrival of the transverse wave, the location of the target formation below the surface in the wellhead is determined, and the first calculated depth of the target formation location is determined.

[0012] Based on the first arrival of the P-wave and the first arrival of the S-wave, a second calculation depth and a third calculation depth are determined above the target stratum location;

[0013] The second time data corresponding to the second calculation depth and the third time data corresponding to the third calculation depth are obtained respectively;

[0014] Based on the second time data and the third time data, the target formation dip angle corresponding to the wellhead in the target region is determined.

[0015] Optionally, determining the target formation dip angle corresponding to the wellhead in the target region based on the second time data and the third time data includes:

[0016] The second time data includes the second upward shear wave calculation time, the second upward longitudinal wave calculation time, the second downward shear wave calculation time, and the second downward longitudinal wave calculation time; the third time data includes the third upward shear wave calculation time, the third upward longitudinal wave calculation time, the third downward shear wave calculation time, and the third downward longitudinal wave calculation time.

[0017] Process the second and third time data to obtain the joint calculation time;

[0018] Based on the joint calculation time, a first calculation angle is determined;

[0019] The dip angle of the target stratum is determined based on the first calculation angle and the joint calculation time.

[0020] Optionally, processing the second and third time data to obtain the joint calculation time includes:

[0021] The arrival time of the first shear wave is obtained at the first calculation depth, and recorded as the first down-going shear wave calculation time.

[0022] The arrival time of the first longitudinal wave is obtained at the first calculation depth, and the starting time of the descending shear wave is recorded as the first descending longitudinal wave calculation time.

[0023] The first downlink P-wave calculation time, the first downlink S-wave calculation time, the second time data, and the third time data are converted from S-wave data to P-wave domain to determine the pseudo-P-wave time of the S-wave; the pseudo-P-wave time of the S-wave includes the second downlink S-wave conversion time, the third downlink S-wave conversion time, the second uplink S-wave conversion time, and the third uplink S-wave conversion time;

[0024] Based on the transverse wave pseudo-longitudinal wave time, longitudinal and transverse wave data are combined to obtain the combined calculation time.

[0025] Optionally, the transverse wave pseudo-P-wave time can be determined using the following formula:

[0026] T′ sd2 =T pd2 ;

[0027] T′ sd3 =T pd3 ;

[0028]

[0029]

[0030] In the formula, T′ sd2 The second downlink shear wave transition time; T′ sd3 The third downlink shear wave transition time; T′ su2 The second upward transverse wave transition time; T′ su3 The third upward transverse wave transition time; T pd2 The calculation time for the second upward longitudinal wave; T pd3 The calculation time for the third upward longitudinal wave; T su2 The calculation time for the second upward shear wave; T su3 The calculation time for the third upward shear wave; T sd2 The calculation time for the second downlink shear wave; T sd3 The calculation time for the third downlink shear wave; T pd1 T is the calculation time for the first downlink P-wave; sd1 The calculation time is for the first downward shear wave.

[0031] Optionally, the step of combining P-wave and S-wave data based on the S-wave pseudo-P-wave time to obtain the combined calculation time includes:

[0032] The joint computation time is determined using the following formula:

[0033]

[0034]

[0035]

[0036]

[0037] In the formula, T d2 For the second downlink joint calculation time; T d3 For the third downlink joint calculation time; T u2 For the second uplink joint calculation time; T u3 This is the third uplink joint calculation time.

[0038] Optionally, determining the first calculation angle based on the joint calculation time includes:

[0039] The first calculation angle is determined using the following formula:

[0040]

[0041] In the formula, γ is the first calculated angle.

[0042] Optionally, determining the target formation dip angle based on the first calculation angle and the joint calculation time includes:

[0043] The dip angle of the target formation can be determined using the following formula:

[0044]

[0045] In the formula, α is the dip angle of the target stratum.

[0046] Optionally, the data preprocessing of the well seismic data includes at least one of the following: random noise suppression, three-component rotation, amplitude compensation, and deconvolution.

[0047] Optionally, when picking up the first arrival wave of the P-wave data and the first arrival wave of the S-wave data of the second P-wave data respectively, the picking positions on the second P-wave data and the second S-wave data are the same and there is no phase difference.

[0048] Secondly, embodiments of this application provide a combined P-wave and S-wave dip angle calculation device, including a basic data acquisition module, a preprocessing module, a first arrival wave acquisition module, a calculation depth determination module, a time data acquisition module, and a calculation module;

[0049] The basic data acquisition module is used to generate seismic waves at a preset point at the wellhead in the target area, and receive the well seismic data generated by the seismic waves through a detector set in the wellhead. The well seismic data includes first P-wave data and first S-wave data.

[0050] The preprocessing module is used to preprocess the first longitudinal wave data and the first transverse wave data respectively to obtain the second longitudinal wave data and the second transverse wave data.

[0051] The first arrival wave acquisition module is used to pick up the first arrival wave of the longitudinal wave data and the first arrival wave of the transverse wave data of the second longitudinal wave data respectively.

[0052] The calculation depth determination module determines the location of the target formation below the surface in the wellhead based on the first arrival waves of the longitudinal wave and the first arrival waves of the transverse wave, and determines the first calculation depth of the target formation location.

[0053] The time data acquisition module is used to acquire the second time data corresponding to the second calculation depth and the third time data corresponding to the third calculation depth, respectively.

[0054] The calculation module determines the target formation dip angle corresponding to the wellhead in the target region based on the second time data and the third time data.

[0055] Beneficial effects: This application acquires wellbore seismic data, processes the first P-wave and first S-wave data, and then, based on the obtained second P-wave and second S-wave data, acquires the first arrival waves of the S-wave and P-wave. It then determines the first, second, and third calculation depths based on these first arrival waves, and acquires the second time data corresponding to the second calculation depth and the third time data corresponding to the third calculation depth. By combining the second and third time data and employing multiple data sources, the corresponding formation dip angle is calculated, thus improving the accuracy of formation dip angle calculation. This approach provides higher calculation accuracy for various complex formations, supporting the estimation of geological structures and oil and gas reserves. Attached Figure Description

[0056] To more clearly illustrate the technical solutions of the embodiments of this application, the drawings used in the description of the embodiments of this application will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0057] Figure 1 This is a flowchart of the calculation method proposed in one embodiment of this application;

[0058] Figure 2 This is the first calculated depth on the first arrival waves of the longitudinal wave and the first arrival waves of the transverse wave in the calculation method proposed in one embodiment of this application;

[0059] Figure 3 This is a flowchart of a sub-step of step S107 of the calculation method proposed in an embodiment of this application;

[0060] Figure 4 This is a schematic diagram of transverse wave data to longitudinal wave data conversion according to an embodiment of this application;

[0061] Figure 5 This is a schematic diagram illustrating the relationship between the target stratum dip angle and the first calculated angle according to an embodiment of this application;

[0062] Figure 6 This is a functional block diagram of a computing device proposed in another embodiment of this application. Detailed Implementation

[0063] The technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this application, not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0064] Example 1

[0065] Reference Figure 1 The flowchart illustrates the steps of a method for calculating the dip angle of a combined P-wave and S-wave formation according to an embodiment of the present invention. Figure 1 As shown, this calculation method may specifically include the following steps:

[0066] S101, a seismic wave is emitted at a preset point at the wellhead in the target area, and the well seismic data generated by the seismic wave is received by a detector installed in the wellhead. The well seismic data includes first P-wave data and first S-wave data.

[0067] When acquiring borehole seismic data for the target area, a method is used that involves excitation from a surface seismic source and acquisition by a geophone installed in the borehole. Borehole seismic data can better reflect the actual stratigraphic conditions. In this implementation, borehole seismic data is used as the basic data required for calculation, which can improve the calculation accuracy.

[0068] S102, perform data preprocessing on the first longitudinal wave data and the first transverse wave data respectively to obtain the second longitudinal wave data and the second transverse wave data;

[0069] The first P-wave data and the first S-wave data are the raw data. Before calculation, the first P-wave data and the first S-wave data need to be processed to obtain the waveform data of the strata in the target area, namely the second P-wave data and the second S-wave data. After processing, the waveforms of the second P-wave data and the second S-wave data are clearer and can be directly used in the calculation.

[0070] S103, respectively pick up the first arrival wave of the longitudinal wave data and the first arrival wave of the transverse wave data of the second longitudinal wave data;

[0071] After processing the first longitudinal wave data and the first transverse wave data, the first arrival waves of the longitudinal wave and the transverse wave of the second longitudinal wave data and the second transverse wave data need to be picked up. After processing the first transverse wave data and the second transverse wave data, the first arrival waves of the longitudinal wave and the transverse wave of the second transverse wave data and the second longitudinal wave data are clear and have a crisp start, which can meet the requirement of accurate first arrival picking.

[0072] S104, Based on the first arrival waves of the longitudinal wave and the first arrival waves of the transverse wave, determine the location of the target formation below the surface in the wellhead, and determine the first calculated depth of the target formation location;

[0073] The first calculation depth is the target formation depth at the desired formation dip angle. In this embodiment, the target formation should be located on the same straight line as the wellhead. When calculating the target formation dip angle, the well seismic data at the target formation depth, i.e., the first calculation depth, is used as the basis.

[0074] S105, based on the first arrival of the P-wave and the first arrival of the S-wave, determine the second calculation depth and the third calculation depth located above the target stratum;

[0075] By determining the second and third calculation depths on the first arrival waves of the P-wave and the first arrival waves of the S-wave, more basic data can be obtained for subsequent calculations of the dip angle of the target strata.

[0076] S106, acquire the second time data corresponding to the second computing depth and the third time data corresponding to the third computing depth respectively;

[0077] The second and third time data are obtained by combining the second and third calculation depths into the calculation process of determining the dip angle of the target strata in the target area.

[0078] S107, Based on the second time data and the third time data, determine the target formation dip angle in the target area corresponding to the wellhead.

[0079] By using the basic data obtained in steps S101-S106 and setting the calculation formula, the dip angle of the target strata in the target area can be determined.

[0080] This embodiment acquires wellbore seismic data, processes the first P-wave data and the first S-wave data, and then, based on the obtained second P-wave data and second S-wave data, acquires the first arrival waves of the S-wave and P-wave. A first calculation depth, a second calculation depth, and a third calculation depth are determined from the first arrival waves of the S-wave and P-wave. The second time data corresponding to the second calculation depth and the third time data corresponding to the third calculation depth are acquired, and the second and third time data are combined. By using multiple data sources, the corresponding formation dip angle is calculated, thus improving the accuracy of formation dip angle calculation.

[0081] Example 2

[0082] Reference Figure 2 The diagram illustrates a flowchart of a method for calculating the dip angle of a combined P-wave and S-wave system according to an embodiment of this application. Figure 2 As shown, the calculation method may specifically include the following steps:

[0083] S101, a seismic wave is emitted at a preset point at the wellhead in the target area, and the well seismic data generated by the seismic wave is received by a detector installed in the wellhead. The well seismic data includes first P-wave data and first S-wave data.

[0084] When acquiring the first longitudinal wave data and the first transverse wave data, it is necessary to first set up a pre-excitation point near the wellhead. The pre-excitation point is a source point that meets the zero-well-source-distance VSP acquisition condition. Generally, it is necessary to take into account both the well site operation environment and drilling safety. In addition, the distance between the pre-excitation point and the wellhead needs to meet the zero-well-source-distance excitation distance described in industry standard SY / T 5454.

[0085] After the excitation preset point is set, shear wave source and P-wave source are set at the excitation preset point; a three-component geophone is used in the well to receive the data. The first P-wave data and the first shear wave data are both three-component seismic data with the same recording length, time and depth sampling interval.

[0086] S102, perform data preprocessing on the first longitudinal wave data and the first transverse wave data respectively to obtain the second longitudinal wave data and the second transverse wave data;

[0087] The first P-wave and first S-wave data obtained from well logging are the initial data. The first P-wave and first S-wave data need to be processed to obtain the second P-wave and second S-wave data that can be directly used for calculation.

[0088] When processing the first longitudinal wave data and the first transverse wave data, at least one of the following is included: random noise suppression processing, three-component rotation processing, amplitude compensation processing, and deconvolution processing.

[0089] Among them, three-component rotation processing refers to redistributing the energy of the three-component geophones in the well based on the principle of maximum energy, so as to obtain rotated P-wave and S-wave well seismic data, which can be achieved through various existing commercial software.

[0090] Random noise suppression, amplitude compensation, and deconvolution are performed as required. The second longitudinal wave data and second transverse wave data obtained through preprocessing are characterized by clear first arrival waves and crisp jumps, which can meet the requirements for accurate first arrival picking.

[0091] S103, respectively pick up the first arrival wave of the longitudinal wave data and the first arrival wave of the transverse wave data of the second longitudinal wave data;

[0092] At the initial pickup, the pickup positions on the second P-wave data and the second S-wave data are the same and there is no phase difference; in this embodiment, since the first P-wave data and the first S-wave data are generated by using a P-wave source and a S-wave source, the pickup positions are both the peak extreme positions of the positive wave.

[0093] S104, Based on the first arrival waves of the longitudinal wave and the first arrival waves of the transverse wave, determine the location of the target formation below the surface in the wellhead, and determine the first calculated depth of the target formation location;

[0094] Reference Figure 2 , Figure 2 The first calculated depths on the P-wave first arrival and S-wave first arrival are shown; by determining the first calculated depth of the target stratum location, the ascending P-wave, ascending S-wave, descending P-wave, and descending S-wave at the first calculated depth can be obtained.

[0095] S105, based on the first arrival of the P-wave and the first arrival of the S-wave, determine the second calculation depth and the third calculation depth located above the target stratum;

[0096] The second and third computational depths are in Figure 2 D2 and D3 are respectively. In this embodiment, by determining the second and third calculation depths, the basic data for calculating the dip angle of the target stratum can be further improved.

[0097] When determining the second and third calculation depths, the second calculation depth should be as close as possible to the first calculation depth to distinguish the up-going and down-going waves of the target stratum. The second calculation depth should be a certain distance from the third calculation depth, but this distance should not be too large. Generally, it is best to keep it within a stable velocity layer.

[0098] S106, acquire the second time data corresponding to the second computing depth and the third time data corresponding to the third computing depth respectively;

[0099] The second time data includes the second upward shear wave calculation time, the second upward longitudinal wave calculation time, the second downward shear wave calculation time, and the second downward longitudinal wave calculation time; the third time data includes the third upward shear wave calculation time, the third upward longitudinal wave calculation time, the third downward shear wave calculation time, and the third downward longitudinal wave calculation time.

[0100] In this embodiment, refer to Figure 2 When determining the second and third time data, it is necessary to first find the ascending and descending waves at the second and third calculation depths on the first arrival waves of the longitudinal and transverse waves, and distinguish between the ascending and descending waves. On the ascending waves, find the ascending longitudinal and ascending transverse waves, and on the descending waves, find the descending longitudinal and descending transverse waves.

[0101] S107, Based on the second time data and the third time data, determine the target formation dip angle in the target area corresponding to the wellhead.

[0102] Reference Figure 3 In the above steps, the second time data and the third time data are used as the basic data for calculating the dip angle of the strata in the target area. By combining the second time data and the third time data, the data for calculating the dip angle of the strata are obtained.

[0103] When determining the target formation dip angle corresponding to the wellhead in the target region based on the second time data and the third time data, the following sub-steps are included:

[0104] Reference Figure 3 , Figure 3 The flowchart of the sub-steps of step S107 is shown below:

[0105] Sub-step S1071 processes the second time data and the third time data to obtain the joint calculation time; including:

[0106] The arrival time of the first shear wave is obtained at the first calculation depth, and recorded as the first down-going shear wave calculation time.

[0107] The arrival time of the first longitudinal wave is obtained at the first calculation depth, and the starting time of the descending shear wave is recorded as the first descending longitudinal wave calculation time.

[0108] Reference Figure 4 , Figure 4 The transformation between shear wave and longitudinal wave data in this embodiment is illustrated.

[0109] The first downlink P-wave calculation time, the first downlink S-wave calculation time, the second time data, and the third time data are converted from S-wave data to P-wave domain to determine the pseudo-P-wave time of the S-wave.

[0110] The transverse wave pseudo-longitudinal wave time includes the second down-going transverse wave transition time, the third down-going transverse wave transition time, the second up-going transverse wave transition time, and the third up-going transverse wave transition time.

[0111] The transverse wave pseudo-longitudinal wave time is determined using the following formula:

[0112] T′ sd2 =T pd2 ;

[0113] T′ sd3 =T pd3 ;

[0114]

[0115]

[0116] In the formula, T pd1 T is the calculation time for the first downlink P-wave; sd1 The calculation time for the first downlink shear wave; T′ sd2 The second downlink shear wave transition time; T′ sd3 The third downlink shear wave transition time; T′ su2 The second upward transverse wave transition time; T′ su3 The third upward transverse wave transition time; T pd2 The calculation time for the second upward longitudinal wave; T pd3 The calculation time for the third upward longitudinal wave; T su2 The calculation time for the second upward shear wave; T su3 The calculation time for the third upward shear wave; T sd2 The calculation time for the second downlink shear wave; T sd3 The calculation time is for the third downward shear wave.

[0117] Based on the transverse wave-pseudo-particle time, P-wave and transverse wave data are combined to obtain the combined calculation time; including:

[0118] The joint computation time is determined using the following formula:

[0119]

[0120]

[0121]

[0122]

[0123] In the formula, T d2 For the second downlink joint calculation time; T d3 For the third downlink joint calculation time; T u2For the second uplink joint calculation time; T u3 This is the third uplink joint calculation time.

[0124] Sub-step S1072, based on the joint calculation time, determines the first calculation angle; including:

[0125] The first calculation angle is determined using the following formula:

[0126]

[0127] In the formula, γ is the first calculated angle.

[0128] Sub-step S1073, based on the first calculation angle and the joint calculation time, determines the target stratum dip angle; including:

[0129] The dip angle of the target formation can be determined using the following formula:

[0130]

[0131] In the formula, α is the dip angle of the target stratum.

[0132] Reference Figure 5 , Figure 5 The relationship between the target formation dip angle and the first calculated angle is shown. When calculating the formation dip angle, a virtual seismic source I is set below the depth of the target formation. The angle between the virtual seismic source I and the surface and wellhead is the first calculated angle. The calculation formula for the target formation dip angle can be constructed by using the first calculated angle. The basic data and the first calculated angle are combined to calculate the target formation dip angle.

[0133] This embodiment acquires wellbore seismic data, processes the first P-wave and first S-wave data, and then, based on the obtained second P-wave and second S-wave data, acquires the first arrival waves of the S-wave and P-wave. A first, second, and third calculation depth are determined from the first arrival waves of the S-wave and P-wave. Second time data corresponding to the second calculation depth and third time data corresponding to the third calculation depth are acquired, and the second and third time data are combined. By employing multiple data sources, the corresponding formation dip angle is calculated, thus improving the accuracy of formation dip angle calculation.

[0134] Furthermore, this method for calculating stratigraphic dip angles can be adapted to the calculation of various stratigraphic dip angles. When faced with problems such as the close apparent velocities of P-waves in steep structural strata, large calculation errors, weak development of S-waves in gentle strata, and more complex strata, it has higher calculation accuracy and can provide support for the determination of geological structures and the estimation of oil and gas reserves.

[0135] Example 3

[0136] Based on the same inventive concept Figure 6 The diagram shown is a schematic of a combined P-wave and S-wave dip angle calculation device, with reference to... Figure 6 As shown, the computing device may include: a basic data acquisition module, a preprocessing module, an initial arrival wave acquisition module, a calculation depth determination module, a time data acquisition module, and a calculation module;

[0137] The basic data acquisition module is used to generate seismic waves at a preset point at the wellhead in the target area, and receive the well seismic data generated by the seismic waves through a detector set in the wellhead. The well seismic data includes first P-wave data and first S-wave data.

[0138] The preprocessing module is used to preprocess the first longitudinal wave data and the first transverse wave data respectively to obtain the second longitudinal wave data and the second transverse wave data.

[0139] The first arrival wave acquisition module is used to pick up the first arrival wave of the longitudinal wave data and the first arrival wave of the transverse wave data of the second longitudinal wave data respectively.

[0140] The calculation depth determination module determines the location of the target formation below the surface in the wellhead based on the first arrival waves of the longitudinal wave and the first arrival waves of the transverse wave, and determines the first calculation depth of the target formation location.

[0141] The time data acquisition module is used to acquire the second time data corresponding to the second calculation depth and the third time data corresponding to the third calculation depth, respectively.

[0142] The calculation module determines the target formation dip angle corresponding to the wellhead in the target region based on the second time data and the third time data.

[0143] The various embodiments in this specification are described in a progressive manner, with each embodiment focusing on the differences from other embodiments. The same or similar parts between the various embodiments can be referred to each other.

[0144] Those skilled in the art will understand that embodiments of this application can be provided as methods, apparatus, or computer program products. Therefore, embodiments of this application can take the form of entirely hardware embodiments, entirely software embodiments, or embodiments combining software and hardware aspects. Furthermore, embodiments of this application can take the form of computer program products implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0145] This application describes embodiments with reference to flowchart illustrations and / or block diagrams of methods, terminal devices (systems), and computer program products according to embodiments of this application. It should be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing terminal device to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing terminal device, generate instructions for implementing the flowchart illustrations. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0146] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing terminal device to operate in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0147] These computer program instructions can also be loaded onto a computer or other programmable data processing terminal equipment, causing a series of operational steps to be performed on the computer or other programmable terminal equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable terminal equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0148] Although preferred embodiments of the present application have been described, those skilled in the art, upon learning the basic inventive concept, can make other changes and modifications to these embodiments. Therefore, the appended claims are intended to be interpreted as including the preferred embodiments as well as all changes and modifications falling within the scope of the embodiments of the present application.

[0149] Finally, it should be noted that in this document, relational terms such as "first" and "second" are used only to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or terminal device that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or terminal device. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or terminal device that includes said element.

[0150] This document uses specific examples to illustrate the principles and implementation methods of this application. The descriptions of the above embodiments are only for the purpose of helping to understand the methods and core ideas of this application. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this application. Therefore, the content of this specification should not be construed as a limitation of this application.

Claims

1. A method for calculating stratigraphic dip angle using combined P-wave and S-wave analysis, characterized in that, Includes the following steps: Seismic waves are emitted from a preset point at the wellhead in the target area, and the well seismic data generated by the seismic waves is received by a detector installed in the wellhead. The well seismic data includes first P-wave data and first S-wave data. The first longitudinal wave data and the first transverse wave data are preprocessed to obtain the second longitudinal wave data and the second transverse wave data. Pick up the first arrival wave of the P-wave data and the first arrival wave of the S-wave data of the second P-wave data respectively; Based on the first arrival of the longitudinal wave and the first arrival of the transverse wave, the location of the target formation below the surface in the wellhead is determined, and the first calculated depth of the target formation location is determined. Based on the first arrival of the P-wave and the first arrival of the S-wave, a second calculation depth and a third calculation depth are determined above the target stratum location; The second time data corresponding to the second calculation depth and the third time data corresponding to the third calculation depth are obtained respectively; Based on the second time data and the third time data, the target formation dip angle corresponding to the wellhead in the target area is determined; Determining the target formation dip angle corresponding to the wellhead in the target region based on the second time data and the third time data includes: The second time data includes the second upward shear wave calculation time, the second upward longitudinal wave calculation time, the second downward shear wave calculation time, and the second downward longitudinal wave calculation time; the third time data includes the third upward shear wave calculation time, the third upward longitudinal wave calculation time, the third downward shear wave calculation time, and the third downward longitudinal wave calculation time. Process the second and third time data to obtain the joint calculation time; Based on the joint calculation time, a first calculation angle is determined; The dip angle of the target stratum is determined based on the first calculation angle and the joint calculation time.

2. The method according to claim 1, characterized in that, The process of processing the second and third time data to obtain the joint calculation time includes: The arrival time of the first shear wave is obtained at the first calculation depth, and recorded as the first down-going shear wave calculation time. The arrival time of the first longitudinal wave is obtained at the first calculation depth, and the starting time of the descending shear wave is recorded as the first descending longitudinal wave calculation time. The first downlink P-wave calculation time, the first downlink S-wave calculation time, the second time data, and the third time data are converted from S-wave data to P-wave domain to determine the pseudo-P-wave time of the S-wave; the pseudo-P-wave time of the S-wave includes the second downlink S-wave conversion time, the third downlink S-wave conversion time, the second uplink S-wave conversion time, and the third uplink S-wave conversion time; Based on the transverse wave pseudo-longitudinal wave time, longitudinal and transverse wave data are combined to obtain the combined calculation time.

3. The method according to claim 1, characterized in that, The transverse wave pseudo-longitudinal wave time is determined using the following formula: ； ； ； ； In the formula, This is the second downlink shear wave transition time; This is the transition time for the third downlink shear wave; This is the second upward transverse wave transition time; This is the transition time for the third upward transverse wave; Calculate the time for the second upward longitudinal wave; Calculate the time for the third upward longitudinal wave; Calculate the time for the second upward transverse wave; Calculate the time for the third upward transverse wave; The calculation time for the second downlink shear wave; The calculation time for the third downward shear wave; The calculation time for the first downlink P-wave; The calculation time is for the first downward shear wave.

4. The method according to claim 3, characterized in that, The step of combining S-wave and S-wave data based on the transverse wave pseudo-P-wave time to obtain the combined calculation time includes: The joint computation time is determined using the following formula: ； ； ； ； In the formula, For the second downlink joint calculation time; For the third downlink joint calculation time; For the second uplink joint calculation time; This is the third uplink joint calculation time.

5. The method according to claim 4, characterized in that, Determining the first calculation angle based on the joint calculation time includes: The first calculation angle is determined using the following formula: ； In the formula, This is the first calculated angle.

6. The method according to claim 5, characterized in that, Determining the target formation dip angle based on the first calculation angle and the joint calculation time includes: The dip angle of the target formation can be determined using the following formula: ； In the formula, The dip angle of the target stratum.

7. The method according to claim 1, characterized in that, The data preprocessing of the well seismic data includes at least one of the following: random noise suppression, three-component rotation, amplitude compensation, and deconvolution.

8. The method according to claim 1, characterized in that: When picking up the first arrival of the longitudinal wave in the second longitudinal wave data and the first arrival of the transverse wave in the second transverse wave data respectively, the picking positions on the second longitudinal wave data and the second transverse wave data are the same and there is no phase difference.

9. A device for calculating the dip angle of a formation using combined P-wave and S-wave propagation, characterized in that, It includes a basic data acquisition module, a preprocessing module, a first arrival wave acquisition module, a calculation depth determination module, a time data acquisition module, and a calculation module; The basic data acquisition module is used to generate seismic waves at a preset point at the wellhead in the target area, and receive the well seismic data generated by the seismic waves through a detector set in the wellhead. The well seismic data includes first P-wave data and first S-wave data. The preprocessing module is used to preprocess the first longitudinal wave data and the first transverse wave data respectively to obtain the second longitudinal wave data and the second transverse wave data. The first arrival wave acquisition module is used to pick up the first arrival wave of the longitudinal wave data and the first arrival wave of the transverse wave data of the second longitudinal wave data respectively. The calculation depth determination module determines the location of the target formation below the surface in the wellhead based on the first arrival waves of the P-wave and the first arrival waves of the S-wave, and determines the first calculation depth of the target formation location; and determines the second and third calculation depths above the target formation location based on the first arrival waves of the P-wave and the first arrival waves of the S-wave. The time data acquisition module is used to acquire the second time data corresponding to the second calculation depth and the third time data corresponding to the third calculation depth, respectively. The calculation module determines the target formation dip angle corresponding to the wellhead in the target area based on the second time data and the third time data. Determining the target formation dip angle corresponding to the wellhead in the target region based on the second time data and the third time data includes: The second time data includes the second upward shear wave calculation time, the second upward longitudinal wave calculation time, the second downward shear wave calculation time, and the second downward longitudinal wave calculation time; the third time data includes the third upward shear wave calculation time, the third upward longitudinal wave calculation time, the third downward shear wave calculation time, and the third downward longitudinal wave calculation time. Process the second and third time data to obtain the joint calculation time; Based on the joint calculation time, a first calculation angle is determined; The dip angle of the target stratum is determined based on the first calculation angle and the joint calculation time.

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