Method, system, equipment and medium for automatically updating horizontal well oriented stratum model

Abstract

The invention belongs to the technical field of geophysical exploration, and particularly discloses a method, a system, equipment and a medium for automatically updating a horizontal well oriented stratum model, and the method comprises the following steps: obtaining standard vertical well depth domain seismic data; establishing a stratum model of the standard vertical well; a simulated logging curve is extracted from the established stratum model; automatically explaining the stratum model of the deflecting section of the drilled horizontal well based on correlation analysis; and automatically explaining the stratum model of the horizontal section of the drilled horizontal well based on correlation analysis. According to the method, the stratum model of the standard well is established through the seismic data, the simulated well logging curve and the actual well logging curve are extracted for correlation analysis, efficient and high-precision automatic updating of the stratum model guided by the horizontal well is achieved, and the method is suitable for automatic updating of the stratum model guided by the horizontal well.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of geophysical exploration, in particular to a method, system, device and medium for automatic updating of a formation model for horizontal well steering. BACKGROUND

[0002] In recent years, the exploration and exploitation technology of unconventional oil and gas resources has developed rapidly. The exploration of unconventional oil and gas resources is mainly aimed at finding unconventional oil and gas resources such as oil shale, oil sand, coalbed methane and shale gas. The exploration technology of unconventional oil and gas resources mainly includes geological survey, geophysical exploration and drilling exploration, among which geophysical exploration is the main technical means currently used. The existing exploitation technology of unconventional oil and gas resources mainly includes horizontal well, multi-stage fracturing and other technical means. Through horizontal well steering technology, the contact area with the reservoir can be expanded and the recovery efficiency can be improved. Through multi-stage fracturing technology, the number and length of fractures in the reservoir can be increased, and the permeability of the reservoir can be improved, thereby improving the oil and gas production.

[0003] When using geophysical exploration technology for geological exploration, horizontal well geological steering is an important technology for improving drilling rate and avoiding engineering risks. When drilling a horizontal well, in order to obtain the true shape of the horizontal well formation, artificial methods are usually used for interpretation. The specific operation is as follows: selecting a standard straight well in the work area, comparing the logging curves of the standard straight well and the drilled horizontal well, and adjusting the logging curve data of the standard straight well according to experience to obtain the true shape of the drilled horizontal well formation. This method of obtaining the shape of the horizontal well formation by artificial interpretation has the problems of low precision and accuracy. Moreover, with the increasing number of horizontal well deployments and the increasing drilling speed, the use of artificial interpretation also has the problem of low efficiency. SUMMARY

[0004] To solve the above problems in the prior art, the present application aims to provide a method, system, device and medium for automatic updating of a formation model for horizontal well steering, which realizes automatic updating of the horizontal well formation model based on correlation analysis means to solve the problems of low precision and low efficiency in obtaining the formation shape by artificial interpretation in the prior art.

[0005] To achieve the above-mentioned purpose, the technical method adopted by the present application is as follows: a method for automatic updating of a formation model for horizontal well steering, comprising the following steps:

[0006] S1, establishing an initial seismic velocity field of the work area according to the drilling stratification, time-depth calibration curve and seismic horizon of the standard straight well in the work area, and converting time-domain seismic data using the initial seismic velocity field to obtain depth-domain seismic data.

[0007] S2. Under the constraint of the target layer in the depth domain seismic field, a formation model is established using the stratification and logging curves of standard vertical well data to determine the relationship between the drilled horizontal well build-up section, the horizontal section trajectory and the formation.

[0008] S3. Extract simulated logging curves from the formation model at fixed intervals along the trajectory of the drilled horizontal well;

[0009] S4. Based on correlation analysis, analyze the measured and simulated logging curves of the build-up section, and adjust the formation model to complete the automatic interpretation of the formation model of the build-up section.

[0010] S5. Based on correlation analysis, analyze the measured and simulated logging curves of the horizontal section during drilling, and adjust the formation model to complete the automatic interpretation of the formation model of the horizontal section.

[0011] As a limitation, the specific steps of S4 include:

[0012] S41, the depth measurement range of the inclined section is [md ks ,md ke Using the depth of the stratigraphic model established in S2 as the reference depth, set to 0m, determine the initial depth range (-D, D) for the vertical translation of the stratigraphic model;

[0013] S42, Using the first-level step size Δd L The formation model is translated vertically along the trajectory of the drilled horizontal well. Simulated logging curves F(x) for each translation amount are extracted from the translated formation model, where x∈[md... ks ,md ke ];

[0014] S43. Let the measured curve while drilling in a horizontal well be G(x), where x∈[md] ks ,md ke ] Calculate the correlation coefficient C between the simulated logging curves F(x) and G(x) obtained under various translation amounts. d The correlation calculation formula is:

[0015]

[0016] In the formula and F(x) and G(x) are respectively in the interval [md ks ,md ke The expected value of ];

[0017] Find the maximum correlation coefficient C d max The corresponding translation d max Translate the stratigraphic model by d max ;

[0018] S44. Using the position of the S43 stratigraphic model after translation as the new reference depth, determine the new small-range vertical translation depth range (-D1, D1), using the second-level step size Δd. S The formation model is moved vertically and horizontally. The simulated logging curves F(x) under each translation amount are extracted, and the correlation coefficient C between each simulated logging curve F(x) and G(x) is calculated. d1 Determine the maximum correlation coefficient C dmax1 The corresponding translation d max1 Translate the stratigraphic model by d max1 Repeat this step to further reduce the depth range and translation step size of the vertical translation, when d maxn The calculation stops when the value is 0 or the step size meets the minimum requirement, thus completing the automatic interpretation of the stratigraphic model of the inclined section.

[0019] As a limitation, the specific steps of S5 include:

[0020] S51. The depth measurement range of the horizontal section is x∈[md hs ,md he ], where md hs =md ke Based on the updated stratigraphic model in S4, and using the units divided by the seismic trace data intervals as the basic interpretation units, the dip angle of the horizontal stratigraphic model is adjusted one by one.

[0021] S52. Adjust the dip angle of the first interpretation unit:

[0022] ① Determine the initial adjustment range (-θ, θ) for the formation dip angle; use the first-level angle adjustment step size Δδ L Adjust the dip angle of the formation model along the trajectory of the drilled horizontal well, and extract the simulated logging curve F(x) for each dip angle adjustment, where x∈[md hs ,md cur ], md cur For the depth measurement at the corner point between the current interpretation unit and the well trajectory;

[0023] ② Let the measured curve of a horizontal well while drilling be G(x), where x∈[md hs ,md cur ] Calculate the correlation coefficient C between the simulated logging curves F(x) and G(x) obtained under various adjustment values. δ The correlation calculation formula is:

[0024]

[0025] In the formula and F(x) and G(x) are respectively in the interval [md hs ,md cur The expected value of ];

[0026] ③ Find the maximum correlation coefficient C δmax The corresponding translation δ max Adjust the dip angle δ of the current stratigraphic interpretation unit. max ;

[0027] ④ Using the position after adjusting the dip angle of the stratigraphic model in ③ above as the new reference depth, determine the new small-range adjustment range of the stratigraphic dip angle [-θ1, θ1], and use the second-level angle adjustment step size Δδ S Adjust the dip angle of the formation model, extract the simulated logging curves F(x) under each dip angle adjustment, and calculate the correlation coefficient C between each simulated logging curve F(x) and G(x). δ1 Determine the maximum correlation coefficient C δmax1 The corresponding translation δ max1 Translate the stratigraphic model by δ max1 Repeat this step to further reduce the tilt adjustment range and step size, when δ maxn The calculation stops when the value is 0 or the step size meets the minimum requirement, thus completing the automatic interpretation of the stratigraphic model of this interpretation unit.

[0028] S53. Adjust the dip angle of the next interpretation unit sequentially: Using the adjusted position of the previous interpretation unit as the reference depth of the interpretation unit to be adjusted, adjust the dip angle of the interpretation unit to be adjusted according to the steps in S52, and adjust all interpretation units sequentially until x∈[md] is achieved. hs ,md he Automatic interpretation of the horizontal section stratigraphic model.

[0029] As a further clarification: the logging curves in S2 include gamma logging curves and resistivity curves.

[0030] As a further limitation: the fixed spacing in S3 is 0.1m.

[0031] The present invention also provides an automatic formation model updating system for horizontal well guidance, comprising:

[0032] The depth domain seismic data acquisition unit establishes the initial seismic velocity field of the work area based on the drilling stratification, time-depth calibration curve and seismic horizon of the standard vertical wells in the work area, and uses the initial seismic velocity field to convert the time domain seismic data to obtain the depth domain seismic data.

[0033] The formation model building unit, under the constraint of the target layer of the depth domain seismic data, uses the layered data and logging curves of the standard vertical well data to build a formation model of the relationship between the drilled horizontal well build-up section, the horizontal section trajectory and the formation.

[0034] Extract simulated logging curve units and extract simulated logging curves at fixed intervals in the formation model along the trajectory of the drilled horizontal well.

[0035] The automatic interpretation unit of the formation model in the build-up section analyzes the measured curves and simulated logging curves during drilling in the build-up section based on correlation analysis, and adjusts the formation model to complete the automatic interpretation of the formation model in the build-up section.

[0036] The automatic interpretation unit for the formation model in the horizontal section analyzes the measured and simulated logging curves of the horizontal section based on correlation analysis, and adjusts the formation model to complete the automatic interpretation of the formation model in the horizontal section.

[0037] The present invention also provides an electronic device, including a memory and a processor, wherein the memory stores a computer program, and the processor calls the computer program in the memory to execute the above-described method for automatic updating of formation models for horizontal well guidance.

[0038] The present invention also provides a computer-readable storage medium storing a computer program, which, when executed by a processor, is used to implement the above-described method for automatically updating a formation model for horizontal well guidance.

[0039] By adopting the above technical solution, the beneficial effects achieved by the present invention compared with the prior art are as follows:

[0040] This invention establishes an initial formation model using seismic data, providing a relatively ideal initial value for the automatic updating of the model. Based on correlation analysis, it automatically matches the horizontal well logging data with the formation model's logging data, thereby obtaining the true morphology of the formation and improving the efficiency of horizontal well guidance. A phased, multi-scale, progressive cyclic update method is employed to minimize formation model adjustment errors and improve the accuracy of horizontal well guidance. This invention is applicable to the automatic updating of formation models for horizontal well guidance. Attached Figure Description

[0041] Figure 1 This is a flowchart of the method in Embodiment 1 of the present invention;

[0042] Figure 2 This is a flowchart of step S1 in Embodiment 1 of the present invention;

[0043] Figure 3 This is the superimposed profile of the formation model established under seismic constraints based on standard vertical well logging curves and layering in Embodiment 1 of the present invention, and the depth domain seismic data.

[0044] Figure 4 The correlation coefficient between the simulated curve and the actual drilling curve obtained under the large-scale translational displacement of the guide section in Embodiment 1 of the present invention;

[0045] Figure 5 The stratigraphic model and simulated curve morphology after large-scale translation of the inclined section in Embodiment 1 of the present invention;

[0046] Figure 6 The correlation coefficient between the simulated curve and the actual drilling curve obtained under the small-scale translational displacement of the directional drilling section in Embodiment 1 of the present invention;

[0047] Figure 7 The morphology of the stratigraphic model and simulated curve after the small-scale translation of the inclined section in Embodiment 1 of the present invention;

[0048] Figure 8 This is a schematic diagram of the horizontal segment guidance interpretation unit in Embodiment 1 of the present invention;

[0049] Figure 9 The diagram shows the dip angle of the formation in the horizontal section guiding adjustment interpretation unit in Embodiment 1 of the present invention, wherein: (a) is a diagram of the formation with an adjustment amount of -10 degrees (dip angle of 9.2 degrees downward), (b) is a diagram of the formation with an adjustment amount of 0 degrees, that is, the initial state (dip angle of 0.8 degrees upward), and (c) is a diagram of the formation with an adjustment amount of 10 degrees (dip angle of 10.8 degrees upward).

[0050] Figure 10 The correlation coefficient between the simulated curve and the actual drilling curve obtained under the formation dip angle of the large-scale adjustment interpretation unit of the horizontal segment guidance in Embodiment 1 of the present invention;

[0051] Figure 11 This refers to the stratigraphic model and simulated curve morphology after adjusting the dip angle of the horizontal segment guiding large-scale interpretation unit in Embodiment 1 of the present invention.

[0052] Figure 12 The correlation coefficient between the simulated curve and the actual drilling curve obtained under the formation dip angle of the horizontal segment guide small-scale adjustment interpretation unit in Embodiment 1 of the present invention;

[0053] Figure 13 The stratigraphic model and simulated curve morphology after adjusting the dip angle of the horizontal segment guide small-scale interpretation unit in Embodiment 1 of the present invention;

[0054] Figure 14 This is the automatically updated stratigraphic model of Embodiment 1 of the present invention;

[0055] Figure 15 This is a structural block diagram of the automatic updating system for the stratigraphic model in Embodiment 2 of the present invention. Detailed Implementation

[0056] The preferred embodiments of the present invention will now be described with reference to the accompanying drawings. It should be understood that the preferred embodiments described herein are for illustrative and explanatory purposes only and do not constitute a limitation thereof.

[0057] Example 1: A method for automatic updating of formation models for horizontal well guidance

[0058] Figure 1 The flowchart of the automatic updating method for the stratigraphic model of the present invention includes the following steps performed sequentially:

[0059] S1. Obtain standard vertical well depth domain seismic data, such as Figure 2 The flowchart shown is for this step. The initial seismic velocity field of the work area is established based on the drilling stratification, time-depth calibration curve and seismic horizon of the standard vertical well in the work area. The time-domain seismic data is then converted using the initial seismic velocity field to obtain the depth-domain seismic data.

[0060] S2. Under the constraint of the target layer in the depth domain seismic data, a formation model is established using the layered data and logging curves of the standard vertical well data to establish the relationship between the drilled horizontal well build-up section, the horizontal section trajectory and the formation.

[0061] like Figure 3 As shown, the logging curve in this embodiment is the GR curve (natural gamma ray logging curve). Of course, the logging curve can also be the resistivity curve. The drilled horizontal well trajectory is divided into a build-up section (depth range 3570m~3925m) and a horizontal section (depth range 3925m~5450m). Figure 3 A stratigraphic model relating the directional section and horizontal segment trajectory of the drilled horizontal well to the formation.

[0062] S3. Extract simulated logging curves from the formation model along the drilled horizontal well trajectory at fixed intervals; in this embodiment, gamma curves are extracted at a sampling interval of 0.1m, such as... Figure 3 The black curve shown is the gamma curve measured during drilling in a horizontal well. Figure 3 The gray curves in the image show a poor correlation between the two curves, indicating that the existing formation model cannot accurately reflect the actual drilling formation model of horizontal wells. To obtain a true actual drilling formation model for horizontal wells, adjustments to the existing formation model are necessary.

[0063] S4. Based on correlation analysis, analyze the measured and simulated logging curves of the build-up section, and adjust the formation model to complete the automatic interpretation of the formation model of the build-up section.

[0064] This step specifically includes:

[0065] S41, the depth measurement range of the inclined section is [md ks ,md ke ], where md ks and md keHere are the depth data values. 'md' is an abbreviation for 'measured depth'. The subscript 'k' represents the start point of the shunting motion, 'ks' represents the start point of the shunting motion, and 'ke' represents the end point of the shunting motion. Using the depth of the stratigraphic model established in S2 as the reference depth, set to 0m, the initial depth range (-D, D) for the vertical translation of the stratigraphic model is determined.

[0066] S42, Using the first-level step size Δd L The formation model is moved vertically along the trajectory of the drilled horizontal well, where the first-stage step size is Δd. L The value of is related to the accuracy of the initial seismic velocity field data. Simulated well logging curves F(x) for each translation amount are extracted from the translated formation model, where x∈[md... ks ,md ke F(x) represents a discrete sequence of simulated well logging data with depth x as the abscissa;

[0067] S43. Let the measured curve while drilling in a horizontal well be G(x), where x∈[md] ks ,md ke Let G(x) represent the discrete sequence of logging data obtained during drilling, with depth x as the abscissa. Calculate the correlation coefficient C between the simulated logging curves F(x) and G(x) obtained under various translation values. d The correlation calculation formula is:

[0068]

[0069] In the formula and F(x) and G(x) are respectively in the interval [md ks ,md ke The expected value of ];

[0070] Find the maximum correlation coefficient C d max The corresponding translation d max Translate the stratigraphic model by d max ,

[0071] S44. Using the position of the formation model after translation in S43 as the new reference depth, determine the new small-range vertical translation depth range (-D1, D1). Use a smaller second-level step size ΔdS to translate the formation model vertically. The value of the second-level step size ΔdS is determined based on the new small-range vertical translation depth range (-D1, D1). Extract the simulated logging curves F(x) for each translation amount, and calculate the correlation coefficient C between each simulated logging curve F(x) and G(x). d1 Determine the maximum correlation coefficient C dmax1 The corresponding translation d max1 Translate the stratigraphic model by d max1Repeat this step to further reduce the depth range and translation step size of the vertical translation, when d maxn The calculation stops when the value is 0 or the step size meets the minimum requirement, thus completing the automatic interpretation of the stratigraphic model of the inclined section.

[0072] Specifically, in this embodiment, the depth measurement range of the inclined plane segment [md] ks ,md ke The depth range of the large-scale translation of the stratigraphic model is determined to be [-D, D], with a step size of Δd, from 3570m to 3925m. Based on the current stratigraphic model, the depth range of the vertical translation (-D, D) is defined as [-10m, 10m]. L =The formation model was moved vertically by 1m. Simulated logging curves with translation amounts ranging from -10m to 10m at 1m intervals were extracted from the formation model after translation along the drilled horizontal well trajectory. The correlation coefficient C between each simulated logging curve and the measured logging curve in the range of 3570m to 3925m was calculated. d The calculation results are as follows Figure 4 As shown in the figure, the correlation coefficient C d The maximum value is 0.64 at -6m. At this point, shifting the geological model downwards by 6m yields the following result: Figure 5 The stratigraphic model and simulated curve morphology after the large-scale translation of the inclined section are shown.

[0073] by Figure 5 Using the stratigraphic model as a reference, the depth range for vertical translation is narrowed down, denoted as (-D1, D1) as [-1m, 1m], and a smaller step size Δd is used. S =0.1m vertical translation of the formation model. Simulated logging curves with translation amounts ranging from -1m to 1m at 0.1m intervals are extracted from the formation model after translation along the drilled horizontal well trajectory. The correlation coefficient C between each simulated logging curve and the measured logging curve in the range of 3570m to 3925m is calculated. d1 The calculation results are as follows Figure 6 As shown, the correlation coefficient C d1 The maximum value is found at -0.4m, with a maximum value of 0.69. At this point, shifting the formation model downwards by 0.4m yields the following result: Figure 7 The stratigraphic model and simulated curve morphology of the inclined section with a total translation of -6.4m are shown. In this embodiment, the gamma curve is extracted at a sampling interval of 0.1m, with a relatively small step size Δd. S =0.1m, which meets the accuracy requirements, and the calculation can be stopped, thus completing the automatic interpretation of the formation model of the drilled horizontal well deflection section.

[0074] S5. Based on correlation analysis, analyze the measured and simulated logging curves of the horizontal section during drilling, and adjust the formation model to complete the automatic interpretation of the formation model of the horizontal section.

[0075] The specific steps include:

[0076] S51. The depth measurement range of the horizontal section is x∈[md hs ,md he ], where md hs =md ke ; where md hs and md he The values ​​represent depth data. 'md' is an abbreviation for 'measured depth'. The subscript 'h' represents horizontal, 'hs' represents the start of the horizontal segment, and 'he' represents the end of the horizontal segment. Based on the updated stratigraphic model in S4, and using the units divided by the seismic trace data intervals as the basic interpretation units, the dip angle of the stratigraphic model for each horizontal segment is adjusted sequentially.

[0077] S52. Adjust the dip angle of the first interpretation unit:

[0078] ① Determine the initial adjustment range of the formation dip angle (-θ, θ); use the first-level angle adjustment Δδ L Adjust the dip angle of the formation model along the trajectory of the drilled horizontal well, and extract the simulated logging curve F(x) for each dip angle adjustment, where x∈[md hs ,md cur ], md cur This is the depth measurement value at the corner point between the current interpretation unit and the well trajectory.

[0079] ② Let the measured curve of a horizontal well while drilling be G(x), where x∈[md hs ,md cur ] Calculate the correlation coefficient C between the simulated logging curves F(x) and G(x) obtained under various adjustment values. δ The correlation calculation formula is:

[0080]

[0081] middle and F(x) and G(x) are respectively in the interval [md hs ,md cur The expected value of ];

[0082] ③ Find the maximum correlation coefficient C δmax The corresponding translation δ max Adjust the dip angle δ of the current stratigraphic interpretation unit. max ;

[0083] ④. Using the adjusted dip angle position of the stratigraphic model in ③ above as the new reference depth, determine a new, smaller range for adjusting the stratigraphic dip angle [-θ1, θ1], and adjust Δδ using the second-order angle adjustment. SAdjust the dip angle of the formation model, extract the simulated logging curves F(x) under each dip angle adjustment, and calculate the correlation coefficient C between each simulated logging curve F(x) and G(x). δ1 Determine the maximum correlation coefficient C δmax1 The corresponding translation δ max1 Translate the stratigraphic model by δ max1 Repeat this step to further reduce the tilt adjustment range and step size, when δ maxn The calculation stops when the value is 0 or the step size meets the minimum requirement, thus completing the automatic interpretation of the stratigraphic model for this interpretation unit.

[0084] S53. Adjust the dip angle of the next interpretation unit sequentially: Using the adjusted position of the previous interpretation unit as the reference depth of the interpretation unit to be adjusted, complete the adjustment of the dip angle of the interpretation unit to be adjusted according to the steps in S52. Adjust all interpretation units sequentially until x∈[md] is achieved. hs ,md he Automatic interpretation of the horizontal section stratigraphic model.

[0085] Specifically, in this embodiment, the depth measurement range of the horizontal segment [md] hs ,md he The altitude ranges from 3925m to 5450m. For example... Figure 8 As shown, the stratigraphic model has been divided into several interpretation units due to the intervals of the seismic trace data. Based on the stratigraphic model of the orogenic segment that has been updated in S4, the units divided by the intervals of the seismic trace data are used as the basic interpretation units.

[0086] like Figure 9 As shown, the dip angle of the first interpretation unit is adjusted. The initial dip angle of this interpretation unit is 0.8 degrees updip, and the depth measurement range is [md]. hs ,md cur The depth is 3925m to 3966m. The large-scale adjustment range (-θ, θ) for the dip angle of the first interpretation unit is determined to be (-10 degrees, 10 degrees), using a relatively large step size Δδ. L =1 degree, adjust the dip angle of the formation model along the already drilled horizontal well trajectory, and extract the simulated logging curves under each dip angle adjustment. Calculate the correlation coefficient C between the simulated logging curves F(x) and G(x) obtained under each adjustment within the range from the starting point of the horizontal section (3925m) to the depth measurement of the intersection of the current formation interpretation unit and the trajectory (3966m). δ The calculation results are as follows Figure 10 As shown. The correlation coefficient is at its maximum when the adjustment is 1 degree, with a maximum value of 0.76. At this point, the dip angle of the current interpretation unit in the stratigraphic model is adjusted upward by 1 degree, resulting in an upward dip angle of 1.8 degrees for the stratigraphic model. The result is as follows. Figure 11 The horizontal segment shows the morphology of the stratigraphic model and simulated curves after large-scale adjustment.

[0087] Using the current position after adjusting the dip angle of the stratigraphic model as the new reference depth, the small-scale adjustment range of the dip angle of the new interpretation unit is determined to be (-θ1, θ1) as (-1 degree, 1 degree), using a smaller step size Δδ. S =0.1 degree adjusted formation model, calculate the correlation coefficient C between simulated logging curves F(x) and G(x) obtained under various adjustment values ​​within the range from the starting point of the horizontal degree segment (3925m) to the depth measurement point (3966m) at the intersection of the current formation interpretation unit and the trajectory. δ1 The calculation results are as follows Figure 12 As shown. The correlation coefficient is highest when the adjustment is -0.4 degrees, with a maximum value of 0.76. Adjusting the dip angle of the current interpretation unit of the stratigraphic model downwards by 0.4 degrees results in an updip dip of 1.4 degrees. The adjusted first interpretation unit stratigraphic model and simulation curve morphology are shown below. Figure 13 As shown. In this embodiment, the gamma curve is extracted at a sampling interval of 0.1m, with a small step size Δδ. S = The adjustment range corresponding to the 0.1 degree adjustment has met the accuracy requirements, and the calculation can be stopped, that is, the adjustment of the formation dip angle of the first interpretation unit of the horizontal section of the drilled horizontal well is completed.

[0088] Adjust the dip angle of the next interpretation unit sequentially: Using the adjusted position of the previous interpretation unit as the reference depth, adjust the dip angle of the interpretation unit to be adjusted using the same method as adjusting the dip angle of the first interpretation unit. Adjust all interpretation units sequentially until the sounding range of the horizontal segment is completed. hs ,md he [Automatic interpretation of the stratigraphic model from 3925m to 5450m. The final adjusted result is as follows.] Figure 14 As shown in the figure, the two curves have a strong positive correlation, and the adjusted formation model can truly reflect the formation model of the actual horizontal well drilling.

[0089] Example 2: An Automatic Formation Model Update System for Horizontal Well Guidance

[0090] like Figure 15 The diagram shown is a structural block diagram of an automatic geological model update system, including:

[0091] The depth domain seismic data acquisition unit establishes the initial seismic velocity field of the work area based on the drilling stratification, time-depth calibration curve and seismic horizon of the standard vertical wells in the work area, and uses the initial seismic velocity field to convert the time domain seismic data to obtain the depth domain seismic data.

[0092] The formation model building unit, under the constraint of the target layer of the depth domain seismic data, uses the layered data and logging curves of the standard vertical well data to build a formation model of the relationship between the drilled horizontal well build-up section, the horizontal section trajectory and the formation.

[0093] Extract simulated logging curve units and extract simulated logging curves at fixed intervals in the formation model along the trajectory of the drilled horizontal well.

[0094] The automatic interpretation unit of the formation model in the build-up section analyzes the measured curves and simulated logging curves during drilling in the build-up section based on correlation analysis, and adjusts the formation model to complete the automatic interpretation of the formation model in the build-up section.

[0095] The automatic interpretation unit for the formation model in the horizontal section analyzes the measured and simulated logging curves of the horizontal section based on correlation analysis, and adjusts the formation model to complete the automatic interpretation of the formation model in the horizontal section.

[0096] Example 3: An electronic device

[0097] This embodiment includes a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the method in embodiment 1.

[0098] Example 4: A computer-readable storage medium

[0099] The computer-readable storage medium provided in this embodiment stores a computer program, which, when executed by a processor, is used to implement the method in Embodiment 1.

[0100] The computer-readable storage medium can be a computer storage medium or a communication medium. A communication medium includes any medium that facilitates the transfer of computer programs from one location to another. A computer storage medium can be any available medium accessible to a general-purpose or special-purpose computer. For example, a computer-readable storage medium is coupled to a processor, enabling the processor to read information from and write information to the computer-readable storage medium. Of course, the computer-readable storage medium can also be a component of the processor. The processor and the computer-readable storage medium can reside in an application-specific integrated circuit (ASIC). Alternatively, the ASIC can reside in a user equipment. Of course, the processor and the computer-readable storage medium can also exist as discrete components in a communication device. Specifically, the computer-readable storage medium can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk, or optical disk, etc. The storage medium can be any available medium accessible to a general-purpose or special-purpose computer.

[0101] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of this disclosure, and are not intended to limit them. Although this disclosure has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some or all of the technical features therein. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of this disclosure.

Claims

1. A method for automatic update of a formation model for horizontal well steering, characterized in that, The method comprises the following steps: S1, establishing an initial seismic velocity field of a work area according to drilling stratification, time-depth calibration curves and seismic horizons of a standard straight well in the work area, and converting time-domain seismic data by using the initial seismic velocity field to obtain depth-domain seismic data; S2, establishing a stratigraphic model of a build-up section and a horizontal section trajectory of a drilled horizontal well and a stratum relationship under the constraint of a target horizon of depth-domain seismic data by using stratification data and well logging curves of standard straight well data; S3, extracting simulated well logging curves in the stratigraphic model along the trajectory of the drilled horizontal well at a fixed interval; S4, analyzing build-up section while-drilling measured curves and simulated well logging curves based on correlation analysis, adjusting the stratigraphic model, and completing automatic interpretation of the build-up section stratigraphic model; S5, analyzing the horizontal section while-drilling measured curves and simulated well logging curves based on correlation analysis, adjusting the stratigraphic model, and completing automatic interpretation of the horizontal section stratigraphic model.

2. The method for automatic formation model updating for horizontal well steering according to claim 1, wherein, The S4 comprises the following steps: S41, the depth measurement range of the build-up section is [md ks , md ke ], taking the depth of the stratum model established in S2 as the reference depth, which is set as 0 m, to determine the initial depth range (-D, D) of the stratum model translation up and down; S42, using the first level step size Δd L Translating the stratum model up and down along the drilled horizontal well trajectory, extracting the simulated logging curve F(x) under each translation amount from the translated stratum model, where x ∈ [md ks ,md ke ] S43, the horizontal well drilling measured curve is G(x), wherein x ∈ [md ks ,md ke ], the correlation coefficient C d of the simulated logging curve F(x) obtained under each translation amount and G(x) is calculated, and the correlation calculation formula is: wherein and are the expected values of F(x), G(x) in the interval [md ks ,md ke ] respectively. finding the maximum correlation coefficient C dmax the corresponding translation d max , translating the earth model by d max ; S44. Using the position of the S43 stratigraphic model after translation as the new reference depth, determine the new small-range vertical translation depth range (-D1, D1), using the second-level step size Δd. S The formation model is moved vertically and horizontally. The simulated logging curves F(x) under each translation amount are extracted, and the correlation coefficient C between each simulated logging curve F(x) and G(x) is calculated. d1 Determine the maximum correlation coefficient C dmax1 The corresponding translation d max1 Translate the stratigraphic model by d max1 Repeat this step to further reduce the depth range and translation step size of the vertical translation, when d maxn The calculation stops when the value is 0 or the step size meets the minimum requirement, thus completing the automatic interpretation of the stratigraphic model of the inclined section.

3. The method for automatic formation model updating for horizontal well steering according to claim 1, wherein, The S5 comprises the following steps: S51, the depth measuring range of the horizontal section is x∈[md hs , md he ], wherein md hs = md ke ; based on the stratum model updated in S4, the stratum model inclination of the horizontal section is adjusted one by one with the unit divided by the seismic trace data interval as the basic interpretation unit; S52, adjusting a first interpretation unit stratum dip angle: ①, determine the initial adjustment range of the formation dip angle (-θ, θ); use the first level angle adjustment step size Δδ L Adjust the dip angle of the formation model along the drilled horizontal well trajectory, extract the simulated logging curve F(x) under each dip angle adjustment amount, where x ∈ [md hs ,md cur ], md cur is the current interpretation unit and the sounding angle point of the well trajectory; ②, the measured curve of the horizontal well while drilling is G(x), wherein x ∈ [md hs , md cur ], the correlation coefficient C δ of the simulated logging curve F(x) and G(x) obtained under each adjustment amount is calculated, and the correlation calculation formula is: In and are the expected values of F(x), G(x) on the interval [md hs ,md cur ] respectively. ③、 find the maximum correlation coefficient C δmax corresponding to the translation δ max adjust the current formation interpretation unit formation dip angle δ max ; IV. The position of the stratigraphic model after adjusting the tilt angle in the above-mentioned III is taken as a new reference depth, and a new small-range adjustment range [-θ1, θ1] of the stratigraphic tilt angle is determined, and a second-level angle adjustment step size Δδ is used S The stratigraphic model tilt angle is adjusted, the simulated logging curves F(x) under each tilt angle adjustment amount are extracted, and the correlation coefficients C of each simulated logging curve F(x) and G(x) are calculated δ1 The maximum correlation coefficient C δmax1 corresponding to the translation amount δ max1 is determined, the stratigraphic model is translated by δ max1 ; this step is repeated to further reduce the tilt angle adjustment range and step size, and the calculation is stopped when δ maxn is 0 or the step size meets the minimum requirement, and the automatic interpretation of the stratigraphic model of the interpretation unit is completed; S53, sequentially adjust the stratigraphic dip angle of the next interpretation unit: take the position of the interpretation unit adjusted in the previous step as the reference depth of the interpretation unit to be adjusted, and complete the adjustment of the stratigraphic dip angle of the interpretation unit to be adjusted according to the method in S52. Adjust all the interpretation units in sequence until the automatic interpretation of the horizontal segment stratigraphic model of x∈[md hs ,md he ] is completed.

4. The method for automatic update of a formation model for horizontal well steering according to any one of claims 1-3, characterized in that, The well logging curves in the S2 comprise gamma logging curves and resistivity curves.

5. The method for automatic formation model updating for horizontal well steering according to claim 4, characterized in that: The fixed interval in the S3 is 0.1 m.

6. A formation model automatic updating system for horizontal well steering, characterized in that, The method comprises the following steps: a depth-domain seismic data acquisition unit, which establishes an initial seismic velocity field of a work area according to drilling stratification, time-depth calibration curves and seismic horizons of a standard straight well in the work area, and converts time-domain seismic data by using the initial seismic velocity field to obtain depth-domain seismic data; a stratigraphic model establishment unit, which establishes a stratigraphic model of a build-up section and a horizontal section trajectory of a drilled horizontal well and a stratum relationship under the constraint of a target horizon of depth-domain seismic data by using stratification data and well logging curves of standard straight well data; an extracted simulated well logging curve unit, which extracts simulated well logging curves in the stratigraphic model along the trajectory of the drilled horizontal well at a fixed interval; a build-up section stratigraphic model automatic interpretation unit, which analyzes build-up section while-drilling measured curves and simulated well logging curves based on correlation analysis, adjusts the stratigraphic model, and completes automatic interpretation of the build-up section stratigraphic model; a horizontal section stratigraphic model automatic interpretation unit, which analyzes the horizontal section while-drilling measured curves and simulated well logging curves based on correlation analysis, adjusts the stratigraphic model, and completes automatic interpretation of the horizontal section stratigraphic model.

7. An electronic device, comprising: The method comprises a memory and a processor, the memory stores a computer program, and the processor calls the computer program in the memory to execute the method for automatically updating a stratigraphic model for horizontal well steering according to any one of claims 1-5.

8. A computer-readable storage medium, characterized in that, The computer readable storage medium stores a computer program, and the computer program is executed by the processor to implement the method for automatically updating a stratigraphic model for horizontal well steering according to any one of claims 1-5.

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