Geological steering method, computer equipment and computer program

Abstract

The invention relates to a geosteering method, computer equipment and a computer program, and the method comprises the steps: constructing a stratum position model of a drilling well before drilling according to preset block geological data, and creating a geosteering model according to the stratum position model of the drilling well before drilling; determining a target box curve characteristic of a guide hole well in the geological data of the preset block, and marking a target box according to the target box curve characteristic; the drilling tool is controlled to execute drilling operation according to the geosteering model, and in the drilling process of the horizontal section, a while-drilling azimuth gamma curve is generated according to data collected by the gamma logging instrument; and according to the while-drilling azimuth gamma curve and the target box, the intersection relation between the current drilling trajectory and the stratum is determined, and the drilling trajectory is adjusted in real time according to the intersection relation. The up-and-down cutting relation between the track and the stratum can be determined in real time, and the track is always drilled in a bedding state by dynamically adjusting the track, so that the drilling rate of the reservoir is increased.

Description

Technical Field

[0001] This disclosure relates to the field of geological exploration technology, and in particular to a geological guidance method, computer equipment, and computer program. Background Technology

[0002] With the development of oil drilling technology and the application of various high-tech equipment, such as azimuth logging while drilling and AMR azimuth resistivity logging, drilling speeds are becoming increasingly faster. Furthermore, the development of thin oil layers, unconventional oil reservoirs, and gas reservoirs can all be achieved through horizontal well drilling. Especially in recent years, the development of shale oil, shale gas, and tight gas has placed increasingly higher demands on drilling technology, making efficient, fast, and precise horizontal well drilling technology, particularly geosteering technology, increasingly important.

[0003] Therefore, how to efficiently, quickly, and accurately locate the drill bit within the formation has become an issue that cannot be ignored. For oil and gas exploration and production departments, ensuring the drill bit remains within the target formation during horizontal well drilling—and how to provide geological guidance—is crucial for improving drilling efficiency.

[0004] Under current technology, geological steering technology, with the application of new logging-while-drilling (LOD) technologies, has provided new ideas and directions. However, changes in the LOD curve caused by formation dip, micro-structures, and encountered faults are still not clearly visible. Geological steering methods are still largely based on formation correlation. This involves identifying similarities between characteristic points in the LOD curve and the pilot well through formation correlation, then observing changes in the LOD and gas logging curves, and using human experience to judge the trajectory's passage through the formation. Based on the correlation results, adjustments are then made tentatively to ensure the wellbore trajectory follows the target box.

[0005] Currently, the horizontal sections of shale oil / shale gas formations are generally 1000m-2000m deep. These formations naturally change during deposition, and simply spreading them out for formation correlation cannot account for variations in the drilling curve caused by formation dip angles, micro-structures, and fault development. Furthermore, manual interpretation methods can be flawed due to the inexperience of personnel. As well as well depths and horizontal sections continue to extend, there is an urgent need for faster, dynamic interpretation of the drilled formations. Summary of the Invention

[0006] This disclosure provides a geological navigation method, computer equipment, and computer program. By applying azimuth gamma, the intersection relationship between the trajectory and the strata is indicated, enabling geological navigation engineers to quickly and dynamically interpret the drilled strata.

[0007] In a first aspect, this disclosure provides a geological steering method, in which a gamma logging tool is installed in the drilling tool used for drilling operations, the method comprising:

[0008] A pre-drilling formation model is constructed based on the geological data of the pre-drilling block, and a geological steering model is created based on the pre-drilling formation model.

[0009] Determine the target box curve characteristics of the pilot well in the geological data of the preset block, and mark the target box according to the target box curve characteristics;

[0010] The drilling tool is controlled to perform drilling operations according to the geological steering model, and during the drilling process in the horizontal section, a drilling azimuth gamma curve is generated based on the data collected by the gamma logging tool.

[0011] Based on the azimuth gamma curve during drilling and the target box, the intersection relationship between the current drilling trajectory and the formation is determined, and the drilling trajectory of the drill string is adjusted in real time according to the intersection relationship.

[0012] In some embodiments, generating a drilling azimuth gamma curve based on data collected by the gamma logging tool during drilling in the horizontal section includes:

[0013] During the drilling of the horizontal section, a gamma measurement operation is performed while the drill string is rotating to obtain the gamma value at the current well depth in real time.

[0014] The drilling azimuth gamma curve is generated based on the historical gamma values ​​before the current well depth and the gamma value at the current well depth.

[0015] In some embodiments, the shear relationship includes an upper shear relationship, a layer-parallel shear relationship, and a lower shear relationship, and adjusting the current drilling trajectory according to the shear relationship includes:

[0016] When the intersection relationship is the upper intersection relationship, control the drill string to perform a deflection reduction operation so that the current drilling trajectory does not deviate from the target box;

[0017] When the intersection relationship is the downward intersection relationship, the drill string is controlled to perform an directional increase operation so that the current drilling trajectory does not deviate from the target box;

[0018] When the intersection relationship is the same as the bedding relationship, the drill string is controlled to maintain the current drilling trajectory unchanged.

[0019] In some embodiments, the target box includes:

[0020] The target layer contains geological sweetness.

[0021] In some embodiments, the drilling azimuth gamma curve includes:

[0022] Upper gamma curve and lower gamma curve; among which,

[0023] The upper gamma curve is generated based on the gamma values ​​collected in the first preset region; the lower gamma curve is generated based on the gamma values ​​collected in the second preset region.

[0024] In some embodiments, the step of determining the hierarchical relationship includes:

[0025] When the values ​​of the upper gamma curve and the lower gamma curve change synchronously, the relationship is determined to be the same as the layered relationship.

[0026] In some embodiments, the step of determining the tangent relationship includes:

[0027] The lower gamma curve within the first preset well depth range and the upper gamma curve within the second preset well depth range maintain synchronous changes in their corresponding values ​​as the well depth increases; wherein, the well depth difference between the starting point of the first preset well depth range and the starting point of the second preset well depth range is the first preset step size.

[0028] In some embodiments, the step of determining the downward cutting relationship includes:

[0029] The upper gamma curve within the third preset well depth range and the lower gamma curve within the fourth preset well depth range maintain synchronous changes in their corresponding values ​​as the well depth increases; wherein, the well depth difference between the starting point of the third preset well depth range and the starting point of the fourth preset well depth range is the second preset step size.

[0030] In a second aspect, this disclosure provides a computer device, including a memory, a processor, and a computer program stored in the memory, characterized in that the processor executes the computer program to implement the steps of the method described above.

[0031] Thirdly, this disclosure provides a computer program product, including a computer program, characterized in that, when the computer program is executed by a processor, it implements the steps of the method described above.

[0032] The geological steering method, computer equipment, and computer program disclosed herein can instantly calculate the change in the dip angle of the formation by observing the sequential appearance of the azimuth gamma curve. After superimposing the curve with the trajectory, the vertical tangency relationship between the trajectory and the formation can be determined in real time. By dynamically adjusting the trajectory, the trajectory can be kept in a state of drilling along the formation to improve the reservoir encounter rate. Attached Figure Description

[0033] The present disclosure will be described in more detail below based on embodiments and with reference to the accompanying drawings:

[0034] Figure 1A schematic flowchart of a geological steering method provided in an embodiment of this disclosure;

[0035] Figure 2 A schematic diagram of regional stratigraphic correlation provided in an embodiment of this disclosure;

[0036] Figure 3 A schematic diagram of landing segment feature points and target box information provided in an embodiment of this disclosure;

[0037] Figure 4 This is a schematic diagram of the azimuth gamma when a drilling instrument traverses the same characteristic lithology, provided in an embodiment of this disclosure;

[0038] Figure 5 A schematic diagram of azimuth gamma measurement provided in this embodiment of the present disclosure;

[0039] Figure 6 A schematic diagram (upper cut) of formation dip angle calculated by azimuth gamma during drilling provided in an embodiment of this disclosure;

[0040] Figure 7 This is a schematic diagram illustrating the relationship between the trajectory and the stratigraphy, as well as the relationship between azimuth and gamma variation, provided in an embodiment of this disclosure.

[0041] Figure 8 This is a schematic diagram illustrating the intersection relationship between an azimuth gamma determination trajectory and the stratigraphy, provided as an embodiment of this disclosure.

[0042] In the accompanying drawings, the same parts are referred to by the same reference numerals, and the drawings are not drawn to scale. Detailed Implementation

[0043] To enable those skilled in the art to better understand the technical solutions of this disclosure, and to fully understand and implement the process of how this disclosure applies technical means to solve technical problems and achieve corresponding technical effects, the technical solutions in the embodiments of this disclosure will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this disclosure, not all embodiments. The embodiments of this disclosure and the various features within them can be combined with each other without conflict, and the resulting technical solutions are all within the protection scope of this disclosure. All other embodiments obtained by those skilled in the art based on the embodiments of this disclosure without creative effort should fall within the protection scope of this disclosure.

[0044] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this disclosure are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this disclosure described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0045] It should be noted that the steps shown in the flowchart in the accompanying drawings can be executed in a computer system such as a set of computer-executable instructions, and although a logical order is shown in the flowchart, in some cases the steps shown or described may be executed in a different order than that shown here.

[0046] This application discloses a geological steering method, comprising the following steps: collecting and analyzing regional data (including pilot well data), carefully studying the drilling design data, constructing a pre-drilling geological steering model, and preparing a pre-drilling steering plan; during drilling, based on the loading of the azimuth gamma logging curve, strengthening formation correlation, and in horizontal formations, determining the vertical tangency relationship between the trajectory and the formation by the order of upper and lower gamma logging to guide the geological steering construction of horizontal wells. Specifically, during drilling, azimuth gamma data is loaded into the geological steering software data area, and by analyzing the relationship between the azimuth gamma and the formation, and using an algorithm to calculate the formation dip angle by utilizing the similar characteristics exhibited by the azimuth gamma when crossing the same formation, and issuing timely and effective steering commands based on changes in the formation dip angle; post-drilling, analyzing the advantages and disadvantages of the geological steering process, identifying and addressing shortcomings, and continuously iterating and upgrading to ensure a smooth wellbore trajectory and efficient drilling, providing favorable support for downhole construction. Geological steering methods based on azimuth gamma logging while drilling improve the accuracy of describing micro-strata structures. When the horizontal section is long, direct in-well correlation through azimuth gamma logging increases the accuracy of stratigraphic correlation, providing strong technical support for geological steering of horizontal wells. This is more conducive to timely detection of oil and gas shows, smoothing of wellbore trajectory, and prediction of drilling anomalies, providing a basis for the next step of exploration and development.

[0047] As well depths and horizontal sections continue to increase, there is an urgent need for geosteering engineers to quickly and dynamically interpret the drilled formations. To address this, we have developed a geosteering method based on azimuth gamma logging technology. This method adds segmented interpretation sections to the drilled formations traversed by the wellbore trajectory, uses azimuth gamma logging to determine the intersection relationship between the trajectory and the formation, and then adjusts the dynamic fitting (including stretching, compression, and flipping) of the drilling curve and the pilot well curve in the geosteering software. This adjustment, in turn, refines the actual drilled formation model, creating a dynamic interpretation model to guide subsequent directional drilling operations.

[0048] Furthermore, to ensure the horizontal section continues to traverse within the target formation box, as the horizontal section extends further away from the pilot well, the accuracy of formation correlation becomes significantly compromised when comparing with the pilot well. Therefore, azimuth gamma ray analysis effectively delineates the intersection relationship between the trajectory and the formation, allowing for segmented interpretation of the horizontal section and a clear visual representation of the trajectory's movement within the target formation box. By visually demonstrating this intersection relationship, the following operational methods can be employed to ensure the trajectory traverses the target formation box: if the trajectory cuts above the formation within the horizontal section, the inclination is appropriately lowered to bring the trajectory back to the target formation box; if the trajectory cuts below the formation, the inclination is appropriately increased to bring the trajectory back to the target formation box. Consistent upper and lower gamma ray readings on the drilling curve indicate that the trajectory is aligned with the formation, allowing for continued drilling. Thus, once within the target formation box, azimuth gamma ray analysis provides a clear visual assessment of the trajectory's intersection relationship with the formation. When the geological target is clear, this comparison method can quickly provide the guidance engineer with more convincing and reliable evidence during geological steering.

[0049] Example 1

[0050] This embodiment discloses a geological steering method that can be applied to drilling tools, which are tools used to perform positive wellbore drilling operations in oil drilling.

[0051] Figure 1 This is a schematic flowchart illustrating a geological steering method provided in an embodiment of this disclosure. Figure 1 As shown, a geological guidance method includes:

[0052] Step 110: Construct a pre-drilling well-drilling stratigraphic model based on the geological data of the preset block, and create a geological steering model based on the pre-drilling well-drilling stratigraphic model.

[0053] Optionally, the collection and analysis of geological data for a pre-defined block may include: collecting a complete set of data, such as logging, well logging, and directional well data, as well as seismic profile slices and drilling design data, for a pilot well in the study block. For example, collecting a complete set of data, such as logging, well logging, and directional well data, as well as seismic profile slices and drilling design data, for a pilot well in the study block; including regional adjacent well geological data, basic data (e.g., wellhead coordinates, elevation, geographical location, core height, etc.), well logging data (e.g., natural gamma, resistivity, sonic transit time, density, neutron logging, etc.), directional well data (e.g., well inclination, azimuth, etc.), and logging data (e.g., drilling time, gas logging, lithological description, geological stratification, engineering anomaly prediction, well leakage, well kick, engineering complexity, etc.), and establishing single-well datasets respectively.

[0054] Then, based on the geological data of the pre-set block, a geological steering model is constructed, which involves analyzing pilot well data and drilling design data, combining regional adjacent well geological data, and finely dividing the geological strata to draw up a well profile for over-drilling (see reference). Figure 2 The target layer where the "geological sweet spot" selected from the pilot well is located (see reference). Figure 3 Create a pre-drilling formation model and establish a geological steering model.

[0055] Step 120: Determine the target box curve characteristics of the pilot well in the geological data of the preset block, and mark the target box according to the target box curve characteristics.

[0056] In some embodiments, the target box includes:

[0057] The target layer contains geological sweetness.

[0058] Based on the geological data of the pre-defined block, obtain the target box curve characteristics of the pilot well and clearly mark the target box information (refer to...). Figure 3 ), and select feature points for the landing segment and the horizontal segment.

[0059] Step 130: Control the drilling tool to perform drilling operations according to the geological steering model, and generate a drilling azimuth gamma curve based on the data collected by the gamma logging tool during the drilling process in the horizontal section.

[0060] In some embodiments, generating a drilling azimuth gamma curve based on data collected by the gamma logging tool during drilling in the horizontal section includes:

[0061] During the drilling of the horizontal section, a gamma measurement operation is performed while the drill string is rotating to obtain the gamma value at the current well depth in real time.

[0062] The drilling azimuth gamma curve is generated based on the historical gamma values ​​before the current well depth and the gamma value at the current well depth.

[0063] In some embodiments, the drilling azimuth gamma curve includes:

[0064] Upper gamma curve and lower gamma curve; among which,

[0065] The upper gamma curve is generated based on the gamma values ​​collected in the first preset region; the lower gamma curve is generated based on the gamma values ​​collected in the second preset region.

[0066] Specifically, based on the measurement principle of azimuth gamma (see reference...) Figure 6 The azimuth gamma downhole measurement system is placed within a device that receives gamma signals in only one direction, while the other directions are blocked. As the drill string rotates, it rotates the azimuth sensor, thus focusing the measurement on only one area. The circumferential section of the wellbore measured by the focused gamma drilling tool (also known as a gamma sensor) is divided into eight measurement sectors, from 0 to 7 (see reference). Figure 5 The focused gamma sensor performs gamma measurements only when the drill string is rotating. As the drill string rotates, the focused gamma sensor rotates with it, collecting and measuring gamma rays from various sectors on the circumferential cross-section of the wellbore. This yields the numerical values ​​of the gamma ray intensity corresponding to each sector on the cross-section.

[0067] The first preset area can be set to sector 0 and sector 7; the second preset area can be set to sector 3 and sector 4.

[0068] The specific process of gamma ray acquisition and measurement for each sector by the focused gamma sensor may include: the angle sensor at the top of the azimuth gamma probe measures the orientation of the focused gamma sensor opening every 16ms. The azimuth gamma downhole measurement system sets the data acquisition period for azimuth gamma to 24s. During this 24s data acquisition period, the azimuth gamma probe rotates with the drill string. During the rotation, the system determines the current orientation of the focused gamma sensor opening every 16ms based on the value of the tool face of the focused gamma sensor opening provided by the angle sensor, thereby determining the sector corresponding to the focused gamma sensor opening. The gamma value can be calculated by combining the following formula (1).

[0069]

[0070] In equation (1): i is the sector number, which is an integer;

[0071] G i API represents the gamma ray intensity corresponding to sector i.

[0072] P i The total number of gamma pulse counts allocated to sector i in one detection cycle, which is an integer;

[0073] Ti The total time, measured in milliseconds, during which sector i is scanned and measured by the focused gamma sensor in one detection cycle;

[0074] K is the compensation coefficient for gamma pulse counting measurement, and it is a decimal.

[0075]

[0076] In equation (2): UPGR is the upper gamma ray intensity value, API;

[0077] P0 and P7 are the gamma-ray pulse counts assigned to sectors 0 and 7, respectively, and are integers.

[0078] T0 and T7 are the total time measured by the focused gamma sensor when sectors 0 and 7 are scanned and measured, respectively, in milliseconds;

[0079] K is the compensation coefficient for gamma pulse counting measurement, and it is a decimal.

[0080]

[0081] In equation (3): DNGR—gamma ray intensity value API in the lower region;

[0082] P3 and P4 are the gamma-ray pulse counts assigned to sectors 3 and 4, respectively, and are integers.

[0083] T3 and T4 are the total time measured by the focused gamma sensor when sectors 3 and 4 are scanned and measured, respectively, in milliseconds;

[0084] K is the compensation coefficient for gamma pulse counting measurement, and is a decimal.

[0085] By combining the tangential relationship between the drill string and the formation, the formation dip angle is derived and calculated, and the dip angle is then adjusted based on the tangential relationship between the drill string and the formation along the drilling trajectory. (Reference) Figure 6 When the well depth is H1, the GR measured by sectors 0 and 7 of the azimuth gamma detector can be included in the upper gamma. The area occupied by sectors 0 and 7 is taken as the upper 1 / 4 of the wellbore radius, that is, the position point after averaging the values ​​of sectors 0 and 7 is O. When the well depth is H2, the GR measured by sectors 3 and 4 of the azimuth gamma detector can be included in the lower gamma. The area occupied by sectors 3 and 4 is taken as the lower 1 / 4 of the wellbore radius, that is, the position point after averaging the values ​​of sectors 3 and 4 is B. Draw a perpendicular line from point O along the drill string direction to point H2 to obtain point A. That is, segment OA is the distance when the upper and lower gamma values ​​are the same, and segment AB is a fixed value, that is, 3 / 4 of the wellbore diameter. ∠AOB can be calculated from △OAB, see equation (4); then, combined with the well inclination angle α, the formation dip angle β can be obtained, see equation (5).

[0086]

[0087] β=α-∠AOB (5)

[0088] In the above formula, the well inclination angle α is the angle measured by MWD during actual drilling; the formation dip angle β is the angle between the formation direction and the vertical direction.

[0089] The calculated formation dip angle is derived from the above principles. When cutting upwards into the formation, the calculated formation dip angle is smaller than the well inclination angle, requiring a decrease in inclination to follow the next layer. When cutting downwards into the formation, the trajectory needs to be adjusted to increase inclination to follow the next layer (see reference). Figure 7 To convert to the actual formation dip angle, it needs to be converted to a horizontal direction. A positive actual formation dip angle indicates a downdip formation, zero indicates a horizontal formation, and a negative actual dip indicates an updip formation. Based on these principles, in horizontal well construction, it is possible to avoid missing the target formation, and even if the target formation is encountered, it can be returned to the target formation in a timely manner, thereby improving the reservoir encounter rate.

[0090] Step 140: Determine the tangent relationship between the current drilling trajectory and the formation based on the drilling azimuth gamma curve and the target box, and adjust the drilling trajectory of the drill string in real time according to the tangent relationship.

[0091] In some embodiments, the shear relationship includes an upper shear relationship, a layer-parallel shear relationship, and a lower shear relationship, and adjusting the current drilling trajectory according to the shear relationship includes:

[0092] When the intersection relationship is the upper intersection relationship, control the drill string to perform a deflection reduction operation so that the current drilling trajectory does not deviate from the target box;

[0093] When the intersection relationship is the downward intersection relationship, the drill string is controlled to perform an directional increase operation so that the current drilling trajectory does not deviate from the target box;

[0094] When the intersection relationship is the same as the bedding relationship, the drill string is controlled to maintain the current drilling trajectory unchanged.

[0095] During drilling, real-time azimuth gamma curve data is acquired, and combined with target box information, precise entry into the formation is achieved. After entering the horizontal section, the gamma curve characteristics are analyzed in segments to determine the intersection relationship and guide the geological steering construction of the horizontal well.

[0096] For example, gamma data of stratigraphic lithology show consistency between upper and lower gamma values ​​during instrument measurements, but there are differences between the upper and lower values ​​(see reference). Figure 4 By sequentially determining the intersection relationship between the trajectory and the formation, and updating the drilling azimuth gamma data of the actual well in the formation correlation profile, the intersection relationship between the trajectory of the horizontal section of the actual well and the formation can be determined.

[0097] In some embodiments, the step of determining the hierarchical relationship includes:

[0098] When the values ​​of the upper gamma curve and the lower gamma curve change synchronously, the relationship is determined to be the same as the layered relationship.

[0099] In some embodiments, the step of determining the tangent relationship includes:

[0100] The lower gamma curve within a first preset well depth range and the upper gamma curve within a second preset well depth range exhibit synchronous changes in value as well depth increases. The well depth difference between the starting points of the first and second preset well depth ranges is a first preset step size. The starting point of the first preset well depth range is greater than the starting point of the second preset well depth range.

[0101] It is understandable that the variation pattern of the lower gamma curve with increasing well depth within the first preset well depth range is the same as the variation pattern of the upper gamma curve with increasing well depth within the second preset well depth range. Simply put, if the upper gamma curve changes first, and then the lower gamma curve changes according to the variation pattern of the upper gamma curve, then an upper tangent relationship can be determined.

[0102] In some embodiments, the step of determining the downward cutting relationship includes:

[0103] The upper gamma curve within the third preset well depth interval and the lower gamma curve within the fourth preset well depth interval maintain synchronous changes in their corresponding values ​​as the well depth increases; wherein, the well depth difference between the starting point of the third preset well depth interval and the starting point of the fourth preset well depth interval is a second preset step size. The starting point of the third preset well depth interval is greater than the starting point of the fourth preset well depth interval.

[0104] It is understandable that the variation pattern of the upper gamma curve with increasing well depth within the third preset well depth range is the same as the variation pattern of the lower gamma curve with increasing well depth within the fourth preset well depth range. Simply put, if the lower gamma curve changes first, and then the upper gamma curve changes according to the variation pattern of the lower gamma curve, then a downward tangent relationship can be determined.

[0105] It should be noted that the above preset well depth ranges are all ranges that include the well depth.

[0106] Optionally, the intersection relationship between strata and trajectory can be divided into three categories: overcut, bedding parallel, and downcut. (Reference) Figure 7By varying the azimuth gamma, when the drill bit is drilling, if the upper gamma changes first and then the lower gamma changes, the trajectory cuts upwards through the strata; if the upper and lower gamma changes at the same frequency, the trajectory follows the strata; if the lower gamma value changes first and then the upper gamma value changes, the trajectory cuts downwards through the strata; upward cutting means the trajectory cuts through the strata from bottom to top; following the strata means the trajectory runs nearly parallel to the strata; downward cutting means the trajectory runs through the strata from above. In actual drilling, the optimal running state is following the strata.

[0107] Furthermore, based on the measurement principle of azimuth gamma, the advantages and disadvantages of the geological steering process are analyzed post-drilling, omissions and deficiencies are identified and addressed, and the geological steering model is continuously iterated and upgraded to ensure a smooth wellbore trajectory and efficient drilling, providing favorable support for downhole construction. The entire horizontal well construction process is systematically reviewed post-drilling, with separate descriptions of complex situations encountered, especially in areas with faults, micro-structures, and significant variations in formation dip. The issuance of steering commands is systematically explained, and the methods and strategies for geological steering are iteratively upgraded.

[0108] Example 2

[0109] Based on the above embodiments, this embodiment is a specific application example.

[0110] refer to Figure 8 In a well drilling in a horizontal section, the red and green lines represent the azimuth gamma curves during drilling. At a depth of 3529.30m, based on upper and lower gamma ray analysis, a slight inclination of 81.4° was recommended to subtly incline the formation. Since the trajectory did not change significantly with the formation dip angle, a slight increase in inclination to 81.8° was suggested. Further drilling to 3548.80m, with an actual inclination of 81.8°, showed consistent upper and lower gamma ray values, indicating the trajectory shifted from inclining to in-formation, demonstrating the effectiveness and reliability of the inclination increase recommendation. Continuing drilling to 3577.50m, with an actual inclination of 82.1°, and based on the azimuth gamma ray analysis, the well trajectory shifted from in-formation to inclining the formation. A slight decrease in inclination to 81.8° was recommended, effectively ensuring the trajectory remained within the reservoir and guaranteeing the reservoir encounter rate.

[0111] It should be noted that when fine-tuning the wellbore trajectory, it is recommended that the engineering team use drill pressure control trajectory. Increasing the drill pressure during combined drilling can slightly increase the inclination, while decreasing the drill pressure can slightly decrease the inclination, thereby reducing the directional time and effectively improving drilling efficiency.

[0112] Example 3

[0113] Based on the above embodiments, this embodiment provides a geological guidance system, which includes:

[0114] The geological guidance model creation module is used to construct a pre-drilling stratigraphic model based on the geological data of a preset block, and to create a geological guidance model based on the pre-drilling stratigraphic model.

[0115] The target box marking module is used to determine the target box curve characteristics of the pilot well in the geological data of the preset block, and mark the target box according to the target box curve characteristics;

[0116] The drilling azimuth gamma curve generation module is used to control the drilling tool to perform drilling operations according to the geological steering model, and to generate the drilling azimuth gamma curve based on the data collected by the gamma logging tool during the drilling process in the horizontal section.

[0117] The adjustment module is used to determine the intersection relationship between the current drilling trajectory and the formation based on the drilling azimuth gamma curve and the target box, and to adjust the drilling trajectory of the drill string in real time according to the intersection relationship.

[0118] Those skilled in the art will understand that the modules or steps described above can be implemented using general-purpose computing devices, either centralized on a single computing device or distributed across a network of multiple computing devices. Optionally, they can be implemented using computer-executable program code, thereby allowing them to be stored in a storage device for execution by a computing device. Furthermore, in some cases, the steps shown or described can be performed in a different order than presented herein, or they can be fabricated as separate integrated circuit modules, or multiple modules or steps can be fabricated as a single integrated circuit module.

[0119] Those skilled in the art will understand that, for the sake of convenience and brevity, the specific working process of each module in the geological guidance system can be referred to the corresponding process in the aforementioned method embodiment, and will not be repeated here.

[0120] Example 4

[0121] Based on the above embodiments, this embodiment provides a computer device, including a memory, a processor, and a computer program stored in the memory, wherein the processor executes the computer program to implement the steps of the method described in the above embodiments.

[0122] In some embodiments of this example, a computer-readable storage medium is provided, on which a computer program is stored, characterized in that the computer program, when executed by a processor, implements the steps of the method described in the above embodiments.

[0123] In some embodiments of this example, a computer program product is provided, including a computer program / instructions, characterized in that the computer program, when executed by a processor, implements the steps of the method described in the above embodiments.

[0124] The processor may include, but is not limited to, one or more processors or microprocessors. Each processor may be implemented as an Application Specific Integrated Circuit (ASIC), Digital Signal Processor (DSP), Digital Signal Processing Device (DSPD), Programmable Logic Device (PLD), Field Programmable Gate Array (FPGA), controller, microcontroller, microprocessor, or other electronic component, for executing the methods in the above embodiments.

[0125] Computer-readable storage media can be implemented by any type of volatile or non-volatile storage device or a combination thereof. Computer-readable storage media may include, but are not limited to, random access memory (RAM), read-only memory (ROM), flash memory, EPROM memory, EEPROM memory, registers, and computer storage media (e.g., hard disks, floppy disks, solid-state drives, removable disks, CD-ROMs, DVD-ROMs, Blu-ray discs, etc.).

[0126] Computer-readable storage media may also store at least one computer-executable program / instruction, such as computer-readable instructions. Computer-readable storage media include, but are not limited to, volatile memory and / or non-volatile memory. Volatile memory may include, for example, random access memory (RAM) and / or cache memory. Computer-readable storage media may include, for example, read-only memory (ROM), hard disk, flash memory, etc. For example, a non-transitory computer-readable storage medium may be connected to a computing device such as a computer, and then, when the computing device executes the computer-readable instructions stored on the computer-readable storage medium, the various methods described above can be performed.

[0127] In addition, the computer device may include (but is not limited to) a data bus, an input / output (I / O) bus, a display, and input / output devices (e.g., keyboard, mouse, speakers, etc.).

[0128] The processor can communicate with external devices via the I / O bus through wired or wireless networks.

[0129] In one embodiment, the at least one computer-executable instruction may also be compiled into or comprise a software product / computer program product, wherein one or more computer-executable instructions are executed by a processor to perform the steps of the various functions and / or methods in the embodiments described herein.

[0130] In the embodiments provided in this disclosure, it should be understood that the disclosed apparatus and methods can also be implemented in other ways. The apparatus embodiments described above are merely illustrative; for example, the flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of apparatus, methods, and computer program products according to various embodiments of this disclosure. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code containing one or more executable instructions for implementing a specified logical function. It should also be noted that in some alternative implementations, the functions marked in the blocks may occur in a different order than those marked in the drawings. For example, two consecutive blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in a block diagram and / or flowchart, and combinations of blocks in block diagrams and / or flowcharts, can be implemented using a dedicated hardware-based system that performs the specified function or action, or using a combination of dedicated hardware and computer instructions.

[0131] It should be noted that, in this disclosure, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus 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 apparatus. Without further limitation, an element limited by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0132] While the embodiments disclosed herein are as described above, the foregoing content is merely for the purpose of facilitating understanding of this disclosure and is not intended to limit this disclosure. Any person skilled in the art to which this disclosure pertains may make any modifications and changes in form and detail of the implementation without departing from the spirit and scope of this disclosure; however, the scope of patent protection of this disclosure shall still be determined by the scope defined in the appended claims.

Claims

1. A method of geosteering, characterized in that, A gamma logging tool is installed in the drilling equipment used for drilling operations, and the method includes: A pre-drilling formation model is constructed based on the geological data of the pre-drilling block, and a geological steering model is created based on the pre-drilling formation model. Determine the target box curve characteristics of the pilot well in the geological data of the preset block, and mark the target box according to the target box curve characteristics; The drilling tool is controlled to perform drilling operations according to the geological steering model, and during the drilling process in the horizontal section, a drilling azimuth gamma curve is generated based on the data collected by the gamma logging tool. Based on the azimuth gamma curve during drilling and the target box, the intersection relationship between the current drilling trajectory and the formation is determined, and the drilling trajectory of the drill string is adjusted in real time according to the intersection relationship.

2. The method of claim 1, wherein, During drilling in the horizontal section, the generation of a drilling azimuth gamma curve based on data collected by the gamma logging tool includes: During the drilling of the horizontal section, a gamma measurement operation is performed while the drill string is rotating to obtain the gamma value at the current well depth in real time. The drilling azimuth gamma curve is generated based on the historical gamma values ​​before the current well depth and the gamma value at the current well depth.

3. The method according to claim 1, characterized in that, The shear relationships include upper shear relationships, layer-parallel shear relationships, and lower shear relationships. Adjusting the current drilling trajectory based on the shear relationships includes: When the intersection relationship is the upper intersection relationship, control the drill string to perform a deflection reduction operation so that the current drilling trajectory does not deviate from the target box; When the intersection relationship is the downward intersection relationship, the drill string is controlled to perform an directional increase operation so that the current drilling trajectory does not deviate from the target box; When the intersection relationship is the same as the bedding relationship, the drill string is controlled to maintain the current drilling trajectory unchanged.

4. The method according to claim 1, characterized in that, The target box includes: The target layer contains geological sweetness.

5. The method according to claim 3, characterized in that, The drilling azimuth gamma curve includes: Upper gamma curve and lower gamma curve; among which, The upper gamma curve is generated based on the gamma values ​​collected in the first preset region; the lower gamma curve is generated based on the gamma values ​​collected in the second preset region.

6. The method according to claim 5, characterized in that, The steps for determining the hierarchical relationship include: When the values ​​of the upper gamma curve and the lower gamma curve change synchronously, the relationship is determined to be the same as the layered relationship.

7. The method according to claim 5, characterized in that, The steps for determining the tangency relationship include: The lower gamma curve within the first preset well depth range and the upper gamma curve within the second preset well depth range maintain synchronous changes in their corresponding values ​​as the well depth increases; wherein, the well depth difference between the starting point of the first preset well depth range and the starting point of the second preset well depth range is the first preset step size.

8. The method according to claim 5, characterized in that, The steps for determining the downward cutting relationship include: The upper gamma curve within the third preset well depth range and the lower gamma curve within the fourth preset well depth range maintain synchronous changes in their corresponding values ​​as the well depth increases; wherein, the well depth difference between the starting point of the third preset well depth range and the starting point of the fourth preset well depth range is the second preset step size.

9. A computer device, comprising a memory, a processor, and a computer program stored in the memory, characterized in that, The processor executes the computer program to implement the steps of the method according to any one of claims 1 to 8.

10. A computer program product, comprising a computer program, characterized in that, When executed by a processor, the computer program implements the steps of the method according to any one of claims 1 to 8.

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