Depth domain seismic three-dimensional sedimentary evolution horizontal well while-drilling guiding method

Abstract

The invention discloses a depth domain seismic three-dimensional sedimentary evolution horizontal well steering while drilling method, and belongs to the technical field of petroleum and natural gas exploration and development. A time domain seismic data body and various inversion data bodies of a certain stratum section are converted into a depth domain data body, reservoir three-dimensional space sedimentary evolution is carried out by utilizing the depth domain seismic data and the inversion data bodies, and the depth domain seismic data and the inversion data bodies are analyzed according to the structural form of a depth domain target layer and the reservoir plane evolution law. And horizontal well multi-target true depth and true dip angle design and while-drilling tracking guiding are directly carried out on a depth domain plane and a section. According to the method, the multi-target true depth and true dip angle design is directly carried out on the seismic plane section in the same depth domain of seismic guidance and while drilling; well drilling information is seamlessly connected with an earthquake, and three-dimensional while-drilling tracking and guiding are carried out on the earthquake in real time. And the drilling rate of the horizontal well reaches more than 80%.

Description

Technical Field

[0001] The present invention belongs to the technical field of oil and gas exploration and development, and in particular relates to a deep-domain seismic three-dimensional sedimentary evolution horizontal well steering while drilling method. Background Art

[0002] After decades of exploration and development, mature oil fields in eastern China are now essentially reaching the mid-to-late-stage. Unconventional reservoirs comprise 80-90% of the remaining resources, representing a crucial replacement resource for the future survival and development of the oil fields. Unconventional reservoirs are developed using the conventional vertical well model, with single wells producing only 1-2 tons per day in 3-5 m reservoirs, resulting in low returns. Horizontal wells can increase the length of the reservoir encountered, increasing both daily and cumulative production. In a 1000-1200 m horizontal section, the penetration rate for 3-5 m reservoirs exceeds 80%, enabling single-well production of 8-12 tons per day, effectively realizing the profitable development of unconventional reservoirs. Ensuring the penetration rate is crucial for increasing horizontal well production. In the exploration and evaluation phase of horizontal wells in tight oil reservoirs, mature technologies are lacking. Horizontal well targets and inclination while drilling are designed using depth-domain structural maps derived from time-domain seismic interpretation, which multiply the horizon by velocity. Lateral reservoir variations are determined by geological models, time-domain 2D seismic, and reservoir parameter inversion profiles. Geological models have limited applicability in well-dense areas. Time-domain seismic profile guidance first requires depth-domain horizontal well calibration using time-domain seismic. Because horizontal wells lack acoustic logging while drilling, there's a long buildup before target entry. Borrowing velocities from adjacent vertical wells can lead to significant errors, making it difficult to accurately calibrate the target layer at its seismic location, and the seismic characteristics of the reservoir's lateral variations are difficult to grasp. Secondly, depth-domain structural maps are derived by multiplying the horizon T0 from time-domain seismic interpretation by the average velocity. However, subsurface velocities vary spatially, making it difficult to accurately determine the velocity at each point. This can lead to discrepancies or even inversions between the apparent dip angle of the time-domain seismic profile and the true dip angle of the depth-domain structural map. Once a horizontal well breaks out during drilling, it's impossible to determine whether the cause is formation dip or reservoir change, and the direction and angle of drill bit adjustment are uncertain. If the adjustment direction is opposite to the true dip, it can be impossible to return to the target layer later. The two key factors in horizontal well drilling, structural inclination and lateral distribution of reservoirs, cannot be accurately determined, resulting in an overall low horizontal well oil layer drilling rate, averaging only about 64%. Wells with a drilling rate below 50% account for 20-30%. Horizontal wells with low drilling rates cannot achieve the effective utilization of unconventional oil reservoirs.

[0003] In summary, the following three questions arise:

[0004] 1. Horizontal well logging while drilling lacks acoustic wave curves, and there are problems with accurately calibrating the horizontal well target layer in time domain seismic.

[0005] 2. There is an angular difference between the true dip of the formation in the depth domain and the apparent dip of the seismic profile in the time domain;

[0006] 3. The changing patterns of reservoirs in three-dimensional space in the depth domain. Summary of the Invention

[0007] To address the above-mentioned problems, the present invention proposes a method for guiding horizontal wells while drilling based on three-dimensional seismic sedimentary evolution in the depth domain. The method uses seismic and well logging velocities to establish a three-dimensional velocity field, and uses the constraints and control of seismic interpretation horizons to convert the time-domain seismic data volume and various inversion data volumes of a certain stratigraphic segment into a depth-domain data volume. The depth-domain seismic data and inversion data volume are then used to analyze the three-dimensional sedimentary evolution of the reservoir. Based on the structural morphology of the depth-domain target layer and the planar evolution law of the reservoir, the true depth and true inclination of multiple target points of the horizontal well and tracking and guiding while drilling are directly performed on the depth-domain plane and profile.

[0008] The steps for implementing deep-domain seismic 3D sedimentary evolution while drilling for horizontal wells are as follows:

[0009] S1. Establish a seismic work area in the Jason work area, load seismic data and horizon and fault data interpreted by other software, and well data including wellhead coordinates, core elevation, well trajectory, geological stratification, and various logging curves.

[0010] S2. The seismic geological system of the wells drilled in the deployment area is unified by single-well synthetic record calibration and seismic well comparison calibration to achieve seismic geological stratification.

[0011] S3. Based on the seismic geological system, complete the sedimentary isochronal surface tracing interpretation near the marker layer of the study area and the target layer of the adjacent horizontal well drilling in the time domain seismic. All horizon interpretations meet the interpretation quality control standards and sedimentation compensation principles. Faults are added to the horizon grid and the time T0 contour map is drawn.

[0012] S4. Use the three-dimensional velocity field jointly established by seismic velocity and well velocity to convert the horizons interpreted in the time domain into depth horizons and draw a depth structure map.

[0013] S5. Use the synthetic recording module to calculate the velocity curve of each well and perform consistency correction on the velocity curve. Select the marker layer and sedimentary isochronous surface (T0) interpreted in the time domain as the top and bottom constraining layers. Select the appropriate interpolation method based on the well distribution density, establish a three-dimensional layer velocity model, and extract the layer velocity plane attributes within a certain layer segment.

[0014] S6. Select the time horizon of the nearest marker layer or sedimentary isochronous surface above the target layer and the zero-altitude depth horizon corresponding to the horizon as the reference surface for time-to-depth conversion. Use the three-dimensional layer velocity model in the time domain as a bridge. Through the Jason time-to-depth conversion module, generate a time-to-depth data volume within a certain time window range to obtain a three-dimensional time-to-depth data volume. Convert any time domain data volume into a depth domain data volume. The sampling interval of the depth domain data volume is set to 0.5m.

[0015] S7. Using depth-domain seismic data or inversion data, under the control of the top and bottom depth-domain horizons, continuous layer slices are generated at 0.5m sampling intervals to study reservoir sedimentary evolution. Based on the vertical and horizontal changes in the slice plane and combined with the depth-domain profile characteristics, the three-dimensional spatial evolution law of the target layer in the depth domain is clarified. Based on the spatial distribution and profile characteristics of the target layer, multiple target points and inclination angles of each section of the horizontal well are designed.

[0016] S8. When the horizontal well is drilled to the nearest marker layer or the top surface of the target layer, if the actual drilling depth and the seismic predicted depth have an error of more than 2m, this point is used as a known well to establish the three-dimensional velocity field and repeat steps S4-S7.

[0017] S9, horizontal well tracking and guidance while drilling, without the need for well seismic calibration, loads the drilling data into the Jason work area in real time, realizes real-time update of drilling data in the deep domain seismic three-dimensional space, and performs dynamic tracking and guidance in real time according to the drilling situation.

[0018] S10. Where the inclination of the target layer changes, the adjustment angle is calculated based on the relationship between the inclination of the top surface of the target layer and the inclination of the reference marker layer.

[0019] The beneficial effects of the present invention are as follows: the present invention achieves three goals: 1. Seismic guidance and while drilling are in the same depth domain, and true depth and true inclination design of multiple targets is directly performed on the seismic section; 2. Drilling while drilling information is seamlessly connected with seismic, and three-dimensional while drilling tracking and guidance is performed on the seismic in real time; 3. The horizontal well drilling rate reaches more than 80%.

[0020] The design of multiple target points and multiple sections of dip angles for horizontal wells is carried out on depth-domain seismic and inversion profiles, eliminating the need for horizontal well calibration and conversion between apparent dip angles and true dip angles in time-domain profiles. This solves the calibration problem of horizontal wells on time-domain seismic. In the while-drilling guidance, the three-dimensional spatial sedimentary evolution of the reservoir in the depth domain is utilized to clarify the vertical and horizontal variation patterns of the target layer. Based on the spatial variation position of the reservoir, the true depth of multiple target points and the true dip angle of multiple sections of the formation are designed in advance on the seismic profile. See the attached figure. Figure 5 Compared with the previous geological model and time domain seismic two-dimensional guidance technology, the present invention has solved the problem of the angle difference between the apparent dip angle in the seismic time domain and the true dip angle in the depth domain. Figure 6 The system also provides a time-domain and depth-domain comparative profile. Simultaneously, through the depth-domain sedimentary evolution, it seamlessly connects downhole information with seismic guidance, enabling real-time downhole dynamic tracking and guidance. This allows the drill bit to be guided through the reservoir according to reservoir evolution laws, significantly improving the horizontal well encounter rate.

[0021] The deep-domain seismic three-dimensional sedimentary evolution horizontal well steering technology has been fully promoted and applied in the fields of thin interbeds and thin interlayer tight oil in the southern Songliao Basin. More than 470 designed and steered horizontal wells have been deployed. The oil layer drilling rate of horizontal wells with thin reservoirs of 3-5m is 75%-100%, reaching an average of 83%. The wells with a drilling rate below 50% account for about 3%, playing a leading role in the efficient development of horizontal wells in unconventional oil reservoirs and supporting the large-scale production of tight oil and interlayer shale oil. BRIEF DESCRIPTION OF THE DRAWINGS

[0022] Figure 1 This is a flow chart of the depth domain seismic time-to-depth conversion and while-drilling dynamic correction of the present invention;

[0023] Figure 2 This is a model diagram of the monocline structure and quasi-parallel sedimentary layers of the present invention;

[0024] Figure 3 This is a model diagram of the monoclinic structure and non-parallel sedimentary layers of the present invention;

[0025] Figure 4 This is a model diagram of the non-monoclinic structure and non-parallel sedimentary layers of the present invention;

[0026] Figure 5 This is a depth domain GR inversion profile diagram of the present invention;

[0027] Figure 6 A comparison diagram of horizontal well trajectories of time-domain seismic and depth-domain seismic in the present invention;

[0028] Figure 7 This is a schematic diagram of the seismic geological layer-linked well calibration principle of the present invention;

[0029] Figure 8 This is a schematic diagram of the three-dimensional sedimentary evolution slice of the first set of sand bodies in the depth domain of the present invention;

[0030] Figure 9 Schematic diagram of the depth domain three-dimensional sedimentary evolution slice of the second set of sand bodies of the present invention;

[0031] Figure 10 This is a depth domain trajectory profile of the Q246-19-22 horizontal well of the present invention;

[0032] Figure 11 This is the depth domain sequence evolution and trajectory profile of the R58-13-2 horizontal well area of ​​the present invention. DETAILED DESCRIPTION

[0033] Example 1

[0034] To facilitate understanding of the technical means and objectives of the present invention, the present invention is further described below in conjunction with specific embodiments. A method for guiding horizontal wells while drilling based on three-dimensional seismic sedimentary evolution in the depth domain utilizes seismic and well logging velocities to establish a three-dimensional velocity field. Seismic interpretation of horizon constraints and controls is used to convert a time-domain seismic data volume and various inversion data volumes of a certain stratigraphic segment into a depth-domain data volume. The depth-domain seismic data and inversion data volumes are then used to analyze the three-dimensional sedimentary evolution of the reservoir. Based on the structural morphology of the depth-domain target layer and the planar evolution law of the reservoir, true depth and true inclination design of multiple target points in the horizontal well and tracking and guiding while drilling are performed directly on the depth-domain plane and profile.

[0035] like Figure 1 As shown in the figure, the steps for implementing the horizontal well steering while drilling based on deep-domain seismic 3D sedimentary evolution are as follows:

[0036] (1) Establish a seismic work area in the Jason work area and load seismic data and layer and fault data interpreted by other software. Well data includes wellhead coordinates, core elevation, well trajectory, geological layers, various logging curves, etc.

[0037] (2) The seismic geological system of the wells drilled in the deployment area is realized through the calibration of single well synthetic records and seismic well comparison calibration to achieve unified seismic geological stratification. The principle of unified stratification is: the geological stratification position curve characteristics of each well marker layer are consistent, the correlation coefficient of the synthetic record of the target layer section reaches more than 75%, and the relative position relationship of the vertical and horizontal calibration of the same geological layer on the seismic section is consistent. Figure 7 shown.

[0038] (3) Based on the seismic geological system, the sedimentary isochronal surface tracking interpretation of the marker layer of the study area and the target layer of the adjacent horizontal well drilling is completed in the time domain seismic. The interpretation of all horizons complies with the interpretation quality control standards and the sedimentary compensation principle. Faults are added to the horizon grid and the time T0 contour map is drawn.

[0039] (4) Using the three-dimensional velocity field jointly established by seismic velocity and well velocity, the layers interpreted in the time domain are converted into depth layers and a depth structure map is drawn.

[0040] (5) The velocity curves of each well are calculated using the synthetic recording module, and the velocity curves are corrected for consistency. The marker layer and the sedimentary isochronous surface (T0) interpreted in the time domain are selected as the top and bottom constraint layers. The appropriate interpolation method is selected according to the well distribution density, and a three-dimensional layer velocity model is established. The layer velocity plane attributes within a certain layer segment (such as the fourth layer of the Quan River) are extracted. The plane attributes are balanced in the horizontal direction to avoid the "bull's eye" phenomenon.

[0041] (6) Select the time layer of the nearest marker layer or sedimentary isochronous surface above the target layer and the depth layer at zero altitude corresponding to the layer as the reference surface for time-depth conversion. Use the three-dimensional layer velocity model in the time domain as a bridge and generate a time-depth data volume within a certain time window through the Jason time-depth conversion module. With the three-dimensional time-depth data volume, any data volume in the time domain can be converted into a depth domain data volume. The sampling interval of the depth domain data volume is set to 0.5m (or less).

[0042] (7) Using depth-domain seismic data or inversion data, under the control of the top and bottom depth-domain horizons, continuous layer slices are generated at sampling intervals of 0.5 m (or less) to study reservoir sedimentary evolution. Based on the vertical and horizontal changes in the slice plane and combined with the depth-domain profile characteristics, the three-dimensional spatial evolution law of the target layer in the depth domain is clarified. Based on the spatial distribution and profile characteristics of the target layer, multiple target points and the inclination angle of each section of the horizontal well are designed.

[0043] (8) When the horizontal well is drilled to the nearest marker layer or the top surface of the target layer, the actual drilling depth and the seismic predicted depth have an error of more than 2m. This point is used as a known well to establish the three-dimensional velocity field and repeat steps 4-7.

[0044] (9) Tracking and steering of horizontal wells while drilling does not require well seismic calibration. The drilling data is loaded into the Jason work area in real time, and the drilling data is updated in real time in the deep domain three-dimensional seismic space. Dynamic tracking and steering are carried out in real time according to the drilling situation.

[0045] (10) Where the target layer dip angle changes, the adjustment angle is calculated based on the relationship between the dip angle of the target layer top surface and the dip angle of the reference marker layer. Three geological models are involved: monocline structure and quasi-parallel sedimentary layers, monocline structure and non-parallel sedimentary layers, and non-monocline structure and non-parallel sedimentary layers. The calculation method for each model is shown in the attached figure. Figures 2 to 4 shown.

[0046] The design of multiple target points and multiple sections of dip angles for horizontal wells is carried out on depth-domain seismic and inversion profiles, eliminating the need for horizontal well calibration and conversion between apparent dip angles and true dip angles in time-domain profiles. This solves the calibration problem of horizontal wells on time-domain seismic. In the while-drilling guidance, the three-dimensional spatial sedimentary evolution of the reservoir in the depth domain is utilized to clarify the vertical and horizontal variation patterns of the target layer. Based on the spatial variation position of the reservoir, the true depth of multiple target points and the true dip angle of multiple sections of the formation are designed in advance on the seismic profile. See the attached figure. Figure 5 Compared with the previous geological model and time domain seismic two-dimensional guidance technology, the present invention has solved the problem of the angle difference between the apparent dip angle in the seismic time domain and the true dip angle in the depth domain. Figure 6The system also provides a time-domain and depth-domain comparative profile. Simultaneously, through the depth-domain sedimentary evolution, it seamlessly connects downhole information with seismic guidance, enabling real-time downhole dynamic tracking and guidance. This allows the drill bit to be guided through the reservoir according to reservoir evolution laws, significantly improving the horizontal well encounter rate.

[0047] The deep-domain seismic three-dimensional sedimentary evolution horizontal well steering technology has been fully promoted and applied in the fields of thin interbeds and thin interlayer tight oil in the southern Songliao Basin. More than 470 designed and steered horizontal wells have been deployed. The oil layer drilling rate of horizontal wells with thin reservoirs of 3-5m is 75%-100%, reaching an average of 83%. The wells with a drilling rate below 50% account for about 3%, playing a leading role in the efficient development of horizontal wells in unconventional oil reservoirs and supporting the large-scale production of tight oil and interlayer shale oil.

[0048] Figure 2 It is a model of monocline structure and quasi-parallel sedimentary layers. According to the well logging while drilling, the well trajectory is gradually fine-tuned. The inclination angle can be calculated by simply measuring the distance between two points and the vertical depth difference with the mouse on the depth domain section. That is, the accuracy depends on the structural trend accuracy of the marker layer depth domain.

[0049] Figure 3 It is a model of monocline structure and non-parallel sedimentary layers. Generally, due to insufficient velocity accuracy, actual drilling will inevitably produce depth errors. However, based on well logging information, the depth and error of the target layer can be determined. The erroneous well logging layer is corrected to the relative isochronous reference interface to eliminate the structural error. Based on the well logging, the layer velocity is obtained, and the trajectory from the top surface entry point to the reservoir entry point, the entry point position and the drill bit parameters (x2, t2, θ1) are recalculated. Where:

[0050] or

[0051] Flatten the seismic profile along the structural plane, interpret the ups and downs of the reservoir sedimentary interface based on paleo-geomorphology, and calculate the parameters of the subsequent points based on the first point (x1,θ1).

[0052] is the inclination angle from point i-1 to point i

[0053] is the average logging velocity at the point of entry into the reservoir, Z io Design depth for the layer after leveling;

[0054] Figure 4 It is a non-monoclinal structure and a non-parallel sedimentary layer. Based on the logging velocity, the curved structural surface is divided into approximate monoclinal structural segments, and the (x i ,z i ,θ i ), where θ iis the dip angle of the stratigraphic structure of each section. Based on the logging velocity, the well trajectory and parameters (x2, z2, α1) are recalculated from the top surface to the reservoir entry point, where α1 is the dip angle of the sedimentary reservoir.

[0055] or

[0056] The designed drill bit inclination angle is:

[0057] Flatten the seismic profile along the relative isochronous interface, calculate the subsequent points based on the first point (x1, α1), and the drill bit parameters designed for the i-th reservoir are:

[0058] Where: j—is the Jth structural dip zone, i—is the i-th reservoir surface design point.

[0059] is the inclination angle from point i-1 to point i;

[0060] is the average logging velocity at the point of entry into the reservoir, Z io Design depth for the layer after leveling.

[0061] like Figure 5 As shown in the figure, the target depth and the formation dip of each section are directly designed based on Model 2 on the depth domain inversion profile.

[0062] The front section of the stratum is steeper, with an inclination of 87.6 degrees, while the back section of the stratum becomes gentler, with an inclination of 88.7 degrees.

[0063] like Figure 6 The following is a comparison of time-domain and depth-domain profiles: The horizontal well broke out of the formation at 623 m. Based on the seismic profile, the drill bit remained within the formation. Drilling proceeded at a 90-degree apparent seismic dip, resulting in no reservoir encounters. Post-drilling analysis using the newly invented depth-domain seismic steering method revealed a true dip of 88.7 degrees in the seismic depth domain. Drilling at a 90-degree angle resulted in a breakout, and subsequent upward drilling, at an angle opposite to the actual formation dip, was the primary reason the well ultimately failed to reenter the formation.

[0064] Example 2

[0065] The accuracy of the velocity field is an important part of the horizontal well steering technology for deep-domain seismic three-dimensional sedimentary evolution, which directly affects the accuracy of the layer depth domain and data volume. In establishing the velocity field, vertical well seismic calibration is the key to establishing the time-depth relationship. The principle of well-seismic calibration is to realize the integration of seismic and geological layers. Figure 7 As shown, the characteristics and positions of the stratification curves of each well are consistent, and the relative position relationship of the stratification on the seismic section is consistent.

[0066] The 3D sedimentary evolution steering process in the depth domain of Well Q246-19-22 is based on Figure 3 The plane of the monocline structure and non-parallel sedimentary layer model shown in the figure clearly defines the vertical and horizontal distribution of the target layer ( Figure 8 and Figure 9 As shown in Figure 2). From the perspective of sedimentary evolution and profile characteristics, sedimentary evolution has broken through the vertical resolution limit. The horizontal target layer is divided into three independent sand bodies. The first 150m or so is developed in the upper part, and the reservoir development after 150m is generally in the lower part. The depth domain seismic flat section is used to clarify the drilling direction and angle of each section ( Figure 10 Q246-19-22 drilled accurately into the first sand body, with a horizontal dip of 88.6 degrees. At a point where seismic reflections changed, the driller exited the formation. Based on Model 2 calculations, the steering angle was adjusted downward to 88 degrees. After drilling 76 meters, the driller entered the second sand body. Based on Model 2 calculations, the formation dip was designed to be 90.1 degrees. The dip was gradually adjusted back to 90.2 degrees. After drilling 530 meters, the formation dip changed. Based on Model 2 calculations, the formation dip was designed to be 89.3 degrees. The dip was gradually adjusted back from 90.1 degrees to 89 degrees, and the driller completed the drill at 89 degrees. Over the 1,235-meter horizontal section, the sandstone penetration rate was 86.2%, and the oil layer penetration rate was 85.2%.

[0067] The three-dimensional sedimentary evolution steering process in the depth domain of R58-13-2 well. Figure 2 The monocline structure and quasi-parallel sedimentary layer model shown in the figure are designed. When the difference between sandstone and non-display sandstone cannot be seen on the cross section, sedimentary evolution shows that the front section of the horizontal well is good both above and below, but the upper reservoir of the rear section becomes worse and the lower reservoir is good. During the drilling process, when the oil spot changes to non-display sandstone, the angle is adjusted to decrease. R58-13-2 changes from oil spot to non-display sandstone during drilling. The vertical and horizontal sedimentary evolution reveals that the lower part of the rear section is better than the upper part. The angle is reduced from 91.2 to 90.5 degrees, returning to the oil spot layer. The horizontal section is 963 meters long, with a sandstone drilling rate of 97.1% and an oil layer drilling rate of 89.4%. Figure 11 ).

[0068] Finally, it should be noted that the method for converting earthquake numbers from the time domain to the depth domain in the patent of this invention is applicable to various geological features that can track and interpret continuous stable marker layers on earthquakes, and the three-dimensional sedimentary evolution in the depth domain is applicable to sedimentary rock strata.

[0069] The above description is only a preferred specific embodiment of the present invention, but the scope of protection of the present invention is not limited thereto. Any technician familiar with the technical field, within the technical scope disclosed in the present invention, who makes equivalent replacements or changes based on the technical solutions and concepts of the present invention, should be covered by the scope of protection of the present invention.

Claims

1. A method for horizontal well steering while drilling based on deep-domain seismic three-dimensional sedimentary evolution, characterized in that: A three-dimensional velocity field is established using seismic and well logging velocities. Seismic interpretation of horizon constraints and controls is used to convert the time-domain seismic data and various inversion data volumes of a certain stratigraphic segment into depth-domain data volumes. The depth-domain seismic data and inversion data volumes are then used to analyze the three-dimensional sedimentary evolution of the reservoir. Based on the structural morphology of the depth-domain target layer and the planar evolution law of the reservoir, the true depth and true inclination of multiple targets of horizontal wells and tracking and steering while drilling are performed directly on the depth-domain plane and profile.

2. The method for horizontal well steering while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 1, characterized in that: The steps for implementing deep-domain seismic 3D sedimentary evolution while drilling for horizontal wells are as follows: S1. Establish a seismic work area in the Jason work area, load seismic data and horizon and fault data interpreted by other software, and well data including wellhead coordinates, core elevation, well trajectory, geological stratification, and various logging curves.

3. The method for horizontal well steering while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 2, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S2. The seismic geological system of the wells drilled in the deployment area is unified by single-well synthetic record calibration and seismic well comparison calibration to achieve seismic geological stratification.

4. The method for guiding horizontal wells while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 3, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S3. Based on the seismic geological system, complete the sedimentary isochronal surface tracing interpretation near the marker layer of the study area and the target layer of the adjacent horizontal well drilling in the time domain seismic. All horizon interpretations meet the interpretation quality control standards and sedimentation compensation principles. Faults are added to the horizon grid and the time T0 contour map is drawn. S4. Use the three-dimensional velocity field jointly established by seismic velocity and well velocity to convert the horizons interpreted in the time domain into depth horizons and draw a depth structure map.

5. The method for guiding horizontal wells while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 4, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S5. Use the synthetic recording module to calculate the velocity curve of each well and perform consistency correction on the velocity curve. Select the marker layer and sedimentary isochronous surface (T0) interpreted in the time domain as the top and bottom constraining layers. Select the appropriate interpolation method based on the well distribution density, establish a three-dimensional layer velocity model, and extract the layer velocity plane attributes within a certain layer segment.

6. The method for guiding horizontal wells while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 5, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S6. Select the time horizon of the nearest marker layer or sedimentary isochronous surface above the target layer and the zero-altitude depth horizon corresponding to the horizon as the reference surface for time-to-depth conversion. Use the three-dimensional layer velocity model in the time domain as a bridge. Through the Jason time-to-depth conversion module, generate a time-to-depth data volume within a certain time window range to obtain a three-dimensional time-to-depth data volume. Convert any time domain data volume into a depth domain data volume. The sampling interval of the depth domain data volume is set to 0.5m.

7. The method for guiding horizontal wells while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 6, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S7. Using depth-domain seismic data or inversion data, under the control of the top and bottom depth-domain horizons, continuous layer slices are generated at 0.5m sampling intervals to study reservoir sedimentary evolution. Based on the vertical and horizontal changes in the slice plane and combined with the depth-domain profile characteristics, the three-dimensional spatial evolution law of the target layer in the depth domain is clarified. Based on the spatial distribution and profile characteristics of the target layer, multiple target points and inclination angles of each section of the horizontal well are designed.

8. The method for guiding horizontal wells while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 7, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S8. When the horizontal well is drilled to the nearest marker layer or the top surface of the target layer, if the actual drilling depth and the seismic predicted depth have an error of more than 2m, this point is used as a known well to establish the three-dimensional velocity field and repeat steps S4-S7.

9. The method for guiding horizontal wells while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 8, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S9, horizontal well tracking and guidance while drilling, without the need for well seismic calibration, loads the drilling data into the Jason work area in real time, realizes real-time update of drilling data in the deep domain seismic three-dimensional space, and performs dynamic tracking and guidance in real time according to the drilling situation.

10. The method for guiding horizontal wells while drilling based on deep-domain seismic three-dimensional sedimentary evolution according to claim 9, characterized in that: The steps for implementing the horizontal well steering while drilling for deep-domain seismic 3D sedimentary evolution also include: S10. Where the inclination of the target layer changes, the adjustment angle is calculated based on the relationship between the inclination of the top surface of the target layer and the inclination of the reference marker layer.

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