Maximum wellhead tension determination method and device, processor and storage medium

Abstract

The embodiment of the invention provides a maximum wellhead tension determination method and device, a processor and a storage medium, and relates to the technical field of logging, the method comprises the following steps: determining a target well depth position sequence corresponding to a cable according to the current position of a sticking point when the logging operation is stuck; wherein the target well depth position sequence comprises a plurality of target well depth positions; based on the axial force of the sticking point at the current position, wellhead tension at each target well depth position is determined; and determining the maximum wellhead tension according to the wellhead tension of each target well depth position. According to the method and the device, the wellhead tension at each target well depth position is determined through iterative calculation based on the stress analysis of the logging cable, so that the maximum wellhead tension is determined, the maximum wellhead tension can be determined efficiently and precisely without manual intervention, and the accuracy of the maximum wellhead tension is improved. The problems that the maximum wellhead tension can be roughly estimated only by professional technicians when the well logging operation is stuck, and meanwhile operation is tedious, the speed is low and precision is low are solved.

Description

Technical Field

[0001] This application relates to the field of well logging technology, specifically to a method for determining maximum wellhead tension, a device for determining maximum wellhead tension, a processor, and a storage medium. Background Technology

[0002] In well logging, the cable, pull rod, and logging instrument together constitute the core components of the logging tool. During well logging operations, the surface equipment controls the movement of the cable to lower the pull rod into the well, allowing the logging instrument to contact and measure formation parameters. After the measurement is completed, the pull rod is retrieved to the surface, and the collected data is transmitted to the surface equipment for processing and analysis via the cable.

[0003] Due to complex downhole environments, formation collapse, wellbore narrowing, formation or mud adhesion, and severe dogleg stress, stuck logging frequently occurs during well logging operations. When the logging instrument gets stuck, upward pulling is ineffective, and the wellhead tension increases significantly. When the point of sticking at the connection between the logging instrument and the pull rod reaches the maximum rated tensile force of the pull rod, the pull rod will break, and the logging instrument will fall into the well. Similarly, when the wellhead tension exceeds the cable's ultimate tensile strength, the cable will break, and it will also fall into the well. Since retrieving the logging instrument is usually easier and less costly than retrieving the cable, personnel prefer the pull rod to break rather than the cable when a stuck situation occurs during well logging operations. Therefore, determining the maximum wellhead tension is crucial when a stuck situation occurs during well logging operations. This helps ensure the safety of the logging equipment and operators, and also affects the smooth progress of the logging work.

[0004] In related technologies, determining the maximum wellhead tension when a stuck situation occurs requires specialized technical personnel. This process is cumbersome, slow, and inaccurate, making it difficult to ensure the safety of logging equipment and operators, as well as the smooth progress of logging work. Summary of the Invention

[0005] The purpose of this application is to provide a method, device, processor, and storage medium for determining maximum wellhead tension, in order to solve the problems of cumbersome operation, slow speed, and low accuracy in determining maximum wellhead tension when encountering a stuck state during logging operations.

[0006] To achieve the above objectives, the first aspect of this application provides a method for determining maximum wellhead tension, comprising:

[0007] Based on the current location of the jamming point when the well logging operation encounters a jam, determine the target well depth location sequence corresponding to the cable; wherein, the target well depth location sequence includes multiple target well depth locations;

[0008] Based on the axial force at the current position of the checkpoint, determine the wellhead tension at each of the target well depths;

[0009] The maximum wellhead tension is determined based on the wellhead tension at each target well depth location.

[0010] In this embodiment of the application, determining the target well depth position sequence corresponding to the cable based on the current position of the jamming point when encountering a jam during logging operations includes:

[0011] By pre-setting micro-segments, the cable between the wellhead location and the current location of the jamming point is divided into multiple target micro-segments;

[0012] The target well depth position sequence is generated based on the endpoint values ​​of each target micro-segment within the corresponding well depth range.

[0013] In this embodiment of the application, determining the wellhead tension at each target well depth position based on the axial force at the current position of the checkpoint includes:

[0014] Use the current location of the checkpoint as the target location;

[0015] Determine the axial force and normal force at the target location;

[0016] Based on the axial force and normal force at the target location, determine the wellhead tension at the target location;

[0017] Replace the target well depth position that is preceding and adjacent to the target position in the target well depth position sequence with the target position, and return to the step of determining the axial force and normal pressure of the target position until the wellhead tension of the first element in the target well depth position sequence is determined.

[0018] In this embodiment of the application, determining the axial force and normal force at the target position includes:

[0019] Determine the axial force at the target position based on the maximum rated tensile force of the tension bar;

[0020] The normal force at the target location is determined according to the first formula, which is:

[0021]

[0022] Among them, F N (x) represents the positive pressure at the target location, where x represents the target location; F T (x) represents the axial force at the target location. Let α(x) represent the rate of change of the azimuth angle of the target location, α(x) represent the wellbore inclination angle of the target location, and Δα(x) represent the rate of change of the wellbore inclination angle of the target location. F wΔl represents the unit buoyancy of the cable, and Δl represents the length of the preset micro-segment of the cable.

[0023] In this embodiment of the application, determining the wellhead tension at the target location based on the axial force and normal force at the target location includes:

[0024] The target location is taken as the first location;

[0025] The target well depth position that is preceding and adjacent to the first position in the target well depth position sequence is taken as the second position. Based on the axial force and normal force at the first position, the axial force and normal force at the second position are determined, and the second position is replaced by the first position.

[0026] Determine whether the first position is the first element in the target well depth position sequence. If yes, determine the axial force of the first element in the target well depth position sequence as the wellhead tension of the target position. If no, return to the step of taking the target well depth position in the target well depth position sequence that is before and adjacent to the first position as the second position, until the first position is the first element in the target well depth position sequence.

[0027] In this embodiment of the application, the axial force at the second position is determined according to a second formula, which is:

[0028] F T (x p ) = F w Δlcos[α(x p +Δl)]+μF N (x p +Δl)+F T (x p +Δl);

[0029] Among them, F T (x p ) represents the axial force at the second position, where x p Indicates the second position; F w α(x) represents the unit buoyancy of the cable, Δl represents the length of the preset micro-element segment of the cable, and α(x) represents the buoyancy of the cable. p +Δl) represents the rate of change of the well inclination angle at the first position, μ represents the coefficient of friction between the cable and the well wall, and F N (x p +Δl) represents the positive pressure at the first position, F T (x p +Δl) represents the axial force at the first position.

[0030] In this embodiment of the application, after determining the maximum wellhead tension based on the wellhead tension at each of the target well depth locations, the method further includes:

[0031] The current tension bar used to determine the maximum wellhead tension is taken as the target tension bar. Based on the preset safety factor and the maximum wellhead tension, the safe operating tension is determined. Based on the safe operating tension and the maximum wellhead tension, it is determined whether the target tension bar needs to be replaced.

[0032] If the target tension bar needs to be replaced, the selected new tension bar shall be replaced with the tension bar currently used to determine the maximum wellhead tension; wherein the maximum rated tension of the new tension bar is less than the maximum rated tension of the target tension bar;

[0033] Based on the maximum rated tensile force of the new tension bar, determine the axial force at the current position of the jamming point, and return to execute the step of determining the wellhead tension at each target well depth position based on the axial force at the current position of the jamming point, until it is determined that the target tension bar does not need to be replaced.

[0034] A second aspect of this application provides a device for determining maximum wellhead tension, comprising:

[0035] The location determination module is used to determine the target well depth location sequence corresponding to the cable based on the current location of the jamming point when the logging operation encounters a jam; wherein, the target well depth location sequence includes multiple target well depth locations;

[0036] The wellhead tension determination module is used to determine the wellhead tension at each target well depth position based on the axial force at the current position of the checkpoint.

[0037] The maximum wellhead tension determination module is used to determine the maximum wellhead tension based on the wellhead tension at each of the target well depth locations.

[0038] A third aspect of this application provides a processor configured to perform the above-described method for determining maximum wellhead tension.

[0039] A fourth aspect of this application provides a machine-readable storage medium storing instructions that, when executed by a processor, configure the processor to perform the above-described method for determining maximum wellhead tension.

[0040] The maximum wellhead tension determination method, device, processor, and storage medium provided in this application determine the target well depth position sequence corresponding to the logging cable based on the current position of the jamming point when logging operations encounter a jam. Based on the force analysis of the logging cable within the wellbore at the jamming point, the axial force at the current jamming point is determined. Then, based on the axial force at the current jamming point, the wellhead tension at each of the target well depth positions is determined. This achieves high-efficiency and high-precision determination of the maximum wellhead tension without manual intervention, avoiding the problems of requiring specialized technicians to roughly estimate the maximum wellhead tension when logging operations encounter a jam, as well as the cumbersome operation, slow speed, and low accuracy associated with such methods. Relevant personnel can then process the determined maximum wellhead tension accordingly, ensuring the safety of logging equipment and operators, and the smooth progress of logging operations.

[0041] It should be noted that the determination of the maximum wellhead tension in this application is based on the premise that a stuck situation occurs during logging operations, and the stuck point described in this application represents the stuck point at the connection between the logging instrument and the pull rod, while the maximum wellhead tension represents the maximum wellhead tension experienced by the cable at the wellhead when a stuck situation occurs during logging operations.

[0042] Other features and advantages of the embodiments of this application will be described in detail in the following detailed description section. Attached Figure Description

[0043] The accompanying drawings are provided to further illustrate the embodiments of this application and form part of the specification. They are used together with the following detailed description to explain the embodiments of this application, but do not constitute a limitation on the embodiments of this application. In the drawings:

[0044] Figure 1 The schematic diagram illustrates a flowchart of the method for determining the maximum wellhead tension according to an embodiment of this application;

[0045] Figure 2 The diagram illustrates the calculation process of wellhead tension at each target well depth location in the embodiments of this application.

[0046] Figure 3 This illustration schematically shows a force analysis diagram of the target micro-element segment generated in an embodiment of this application;

[0047] Figure 4 This illustration schematically shows a calculation process for determining the wellhead tension at any of the target well depth locations in an embodiment of this application;

[0048] Figure 5 A wellhead tension curve diagram of an embodiment of this application is illustrated schematically;

[0049] Figure 6 This schematic diagram illustrates the structural block diagram of the maximum wellhead tension determination device according to an embodiment of this application;

[0050] Figure 7 The diagram illustrates the internal structure of a computer device according to an embodiment of this application.

[0051] Explanation of reference numerals in the attached figures

[0052] A01 - Processor; A02 - Network Interface; A03 - Internal Memory; A04 - Display Screen; A05 - Input Device; A06 - Non-volatile Storage Media; B01 - Operating System; B02 - Computer Program. Detailed Implementation

[0053] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are only for illustration and explanation of the embodiments of this application and are not intended to limit the embodiments of this application. All other embodiments obtained by those skilled in the art based on the embodiments of this application without creative effort are within the scope of protection of this application.

[0054] It should be noted that if the embodiments of this application involve directional indicators (such as up, down, left, right, front, back, etc.), the directional indicators are only used to explain the relative positional relationship and movement of the components in a certain specific posture (as shown in the figure). If the specific posture changes, the directional indicators will also change accordingly.

[0055] Furthermore, if the embodiments of this application involve descriptions such as "first" or "second," these descriptions are for descriptive purposes only and should not be construed as indicating or implying their relative importance or implicitly specifying the number of technical features indicated. Therefore, features defined with "first" or "second" may explicitly or implicitly include at least one of those features. Additionally, the technical solutions of various embodiments can be combined with each other, but this must be based on the ability of those skilled in the art to implement them. If the combination of technical solutions is contradictory or impossible to implement, it should be considered that such a combination of technical solutions does not exist and is not within the scope of protection claimed in this application.

[0056] In view of the problem that it is difficult to quickly and accurately determine the maximum wellhead tension when a well log encounters a stuck situation in related technologies, this application provides a method for determining the maximum wellhead tension. The method for determining the maximum wellhead tension provided by this application will be described in detail below with reference to the accompanying drawings and specific embodiments and implementation methods.

[0057] Figure 1 A schematic flowchart illustrating the method for determining the maximum wellhead tension according to an embodiment of this application is shown. Figure 1 As shown, in one embodiment of this application, a method for determining maximum wellhead tension is provided, including the following steps:

[0058] Step 100: Determine the target well depth position sequence corresponding to the cable based on the current location of the jamming point when the well logging operation encounters a jam.

[0059] The target well depth location sequence includes multiple target well depth locations.

[0060] Specifically, the current location of the jamming point refers to its current position within the well, that is, the well depth position of the jamming point at the time of the jamming. It can be understood that each target well depth position in the target well depth position sequence corresponds to a depth within the well.

[0061] In this embodiment, the current position of the checkpoint can be obtained based on instrument data recorded during well logging operations, depth sounding tools, etc., and this application does not limit it. Furthermore, since well logging operations typically use meters to represent well depth, in this embodiment, when the current position of the checkpoint is in meters and the value contains a decimal, it is rounded to retain the integer part for subsequent calculations.

[0062] In this embodiment, step 100 includes:

[0063] Step 110: Divide the cable between the wellhead position and the current position of the jamming point into multiple target micro-segments by pre-setting micro-segments.

[0064] Understandably, when analyzing cables, cable segments can be divided into multiple micro-segments. The smaller the length of each micro-segment, the more accurate the subsequent data calculations and operations will be. In this embodiment, the preset micro-segment can be set according to actual conditions. For example, the length of the preset micro-segment can be set to 1 meter. This application does not limit it.

[0065] The target micro-segment represents a continuous section of cable between the wellhead position and the current position of the checkpoint, and has a certain length. Each target micro-segment has a corresponding depth range in the well. For example, when the preset micro-segment is set to 1 meter, the cable from the wellhead position to a depth of 1 meter in the well is a target micro-segment.

[0066] Step 120: Generate the target well depth position sequence based on the endpoint values ​​of each target micro-segment within the corresponding well depth range.

[0067] Understandably, for two adjacent target micro-segments, their endpoint values ​​share a common value. For example, when the current position of the checkpoint is 1000 meters and the preset micro-segment is 1 meter, the target micro-segment corresponding to the wellhead position to a well depth of 1 meter and the target micro-segment corresponding to the well depth from 1 meter to a well depth of 2 meters have the same endpoint value, i.e., 1 meter. In this case, the generated target well depth position sequence will contain 1001 elements, i.e., 1001 target well depth positions.

[0068] In this embodiment, step 120 specifically includes:

[0069] Based on the numerical values ​​of the endpoints of each target micro-segment within the corresponding well depth range, the target well depth position sequence is generated in ascending order.

[0070] Understandably, in the target well depth position sequence, the wellhead position (with an entry depth of 0) is the first element contained therein, and the current position of the checkpoint is the last element contained therein.

[0071] After determining the current position of the checkpoint, this embodiment can quickly determine the target well depth position sequence based on the preset micro-segment to ensure that the maximum wellhead tension determined based on the wellhead tension of each target well depth position in the target well depth position sequence has good accuracy.

[0072] Step 200: Based on the axial force at the current position of the checkpoint, determine the wellhead tension at each of the target well depth positions.

[0073] Figure 2 This illustration schematically shows a flow chart of the calculation process for wellhead tension at each target well depth location described in the embodiments of this application. For example... Figure 2 As shown, in this embodiment, step 200 includes:

[0074] Step 210: Take the current location of the checkpoint as the target location.

[0075] Step 220: Determine the axial force and normal force at the target location.

[0076] Step 230: Determine the wellhead tension at the target location based on the axial force and normal pressure at the target location.

[0077] Step 240: Replace the target well depth position in the target well depth position sequence that is before and adjacent to the target position with the target position, and return to execute steps 220 to 240 until the wellhead tension of the first element in the target well depth position sequence is determined to be the target position.

[0078] Understandably, for the target location, the axial force and normal pressure at the target location are specifically the forces exerted on the cable located at the target location within the well. Figure 3 The schematic diagram illustrates the force analysis of the target micro-element generated by the embodiments of this application. The axial force at any target well depth is explained below with reference to the accompanying drawings.

[0079] When well logging operations encounter a stuck condition, a force analysis model is established at well depth p corresponding to the target micro-element segment (hereinafter referred to as target micro-element segment p) in the cable, such as... Figure 3 As shown. Figure 3 In the diagram, 0 ≤ p ≤ d, where d represents the current position of the checkpoint, and d ≤ D, where D represents the total depth of the well. Δl represents the length of the preset micro-element segment, and F... T α and F represents the axial force, inclination angle, and azimuth angle of the lower end face of the target micro-element p, respectively. T +ΔF T α+Δα and F represents the axial force, inclination angle, and azimuth angle on the upper surface of the target micro-element p, respectively. N and F w These represent the normal force and buoyancy of the target micro-element p, respectively. The total well depth, the current position of the checkpoint, and the azimuth, azimuth rate of change, inclination angle, and inclination rate of change of each target micro-element can all be obtained from the actual wellbore trajectory and other relevant data. In this embodiment, for any target well depth position, the axial force is the axial force on the lower end face of the corresponding target micro-element.

[0080] In this embodiment, the axial force at the target position is determined based on the maximum rated tensile force of the tension bar. That is, the axial force at the target position is selected as the maximum rated tensile force F of the tension bar. L This is to fully utilize the maximum load-bearing capacity of the tension bar.

[0081] In this embodiment, the positive pressure at the target location is determined according to a first formula, which is:

[0082]

[0083] Among them, F N (x) represents the positive pressure at the target location, where x represents the target location; F T (x) represents the axial force at the target location. Let α(x) represent the rate of change of the azimuth angle of the target location, α(x) represent the wellbore inclination angle of the target location, and Δα(x) represent the rate of change of the wellbore inclination angle of the target location. F w The unit buoyancy of the cable is represented by Δl, which represents the length of the preset micro-segment of the cable.

[0084] Figure 4 This illustration schematically shows a calculation flow diagram for determining the wellhead tension at any of the target well depth locations in an embodiment of this application. For example... Figure 4 As shown, in this embodiment, step 230 includes:

[0085] Step 231: The target position is taken as the first position.

[0086] Step 232: Take the target well depth position that is before and adjacent to the first position in the target well depth position sequence as the second position, determine the axial force and normal force of the second position based on the axial force and normal force of the first position, and replace the second position with the first position.

[0087] In this embodiment, the axial force at the second position is determined according to the second formula, which is:

[0088] F T (x p ) = F w Δlcos[α(x p +Δl)]+μF N (x p +Δl)+F T (x p +Δl);

[0089] Among them, F T (x p ) represents the axial force at the second position, where x p The second position is indicated by μ, which represents the coefficient of friction between the cable and the well wall.

[0090] In this embodiment, the normal force at any target well depth location is calculated using the first formula. When the target well depth location is the target position, the axial force is selected as the maximum rated tensile force F of the tension rod. L When the target well depth position is not the target position, its axial force is calculated using the second formula. It is easy to see that the axial force of any target well depth position other than the last element in the target well depth position sequence (i.e., the current position of the checkpoint) is calculated based on the normal pressure of the target well depth position adjacent to and following it in the target well depth position sequence.

[0091] In addition, in this embodiment, when the second position is the first element in the target well depth position sequence (i.e., the wellhead position), step 232 does not need to calculate the positive pressure at the second position. That is, step 232 is as follows: take the target well depth position that is before and adjacent to the first position in the target well depth position sequence as the second position; if the second position is the first element in the target well depth position sequence, then determine the axial force of the second position based on the axial force and positive pressure at the first position, and replace the second position with the first position; if the second position is not the first element in the target well depth position sequence, then determine the axial force and positive pressure at the second position based on the axial force and positive pressure at the first position, and replace the second position with the first position.

[0092] Step 233: Determine whether the first position is the first element in the target well depth position sequence. If yes, determine the axial force of the first element in the target well depth position sequence as the wellhead tension of the target position. If no, return to step 232 until the first position is the first element in the target well depth position sequence.

[0093] Specifically, for any target well depth position x (0≤x≤d), when the target well depth position is the target position, its wellhead tension can be expressed as:

[0094] T(x)=F T (0)

[0095] Where x represents the target well depth position, d represents the current position of the checkpoint, T(x) represents the wellhead tension at the target well depth position x, and F T (0) represents the axial force of the first element in the target well depth position sequence when the target well depth position is the target position.

[0096] In this embodiment, during each iteration of steps 220 to 240, the axial force and normal force from the first element in the target well depth position sequence to the corresponding element at the target position are recalculated to obtain the wellhead tension at different target well depth positions. It is readily apparent that by treating the wellhead position as point 0 and performing iterative calculations, the wellhead tension at each target well depth position in the target well depth position sequence can be quickly and accurately determined, facilitating the subsequent determination of the maximum wellhead tension.

[0097] Step 300: Determine the maximum wellhead tension based on the wellhead tension at each target well depth location.

[0098] In this embodiment, step 300 includes:

[0099] The maximum wellhead tension is determined based on the maximum value among the wellhead tensions at each target well depth location.

[0100] In one specific embodiment, the maximum value among the wellhead tensions at each of the target well depth locations is taken as the maximum wellhead tension, that is, the maximum wellhead tension can be expressed as:

[0101] T max =max{T(x)}, 0≤x≤d

[0102] Among them, T max This indicates the maximum wellhead tension.

[0103] Optionally, after step 300, the method further includes:

[0104] Step 400: Take the tension bar currently used to determine the maximum wellhead tension as the target tension bar, determine the safe operating tension based on the preset safety factor and the maximum wellhead tension, and determine whether the target tension bar needs to be replaced based on the safe operating tension and the maximum wellhead tension.

[0105] In this embodiment, a safety factor is introduced to prevent the cable from breaking when the well logging operation encounters a jam, namely the preset safety factor. This application does not limit the method of determining the preset safety factor.

[0106] In this embodiment, in step 400, the safe operating tension is determined according to a third formula, which is:

[0107] F T,n =F break / n;

[0108] Among them, F T,n F represents the safe operating tension. break The maximum tensile strength of the cable is represented by , and n represents the preset safety factor. In this embodiment, the maximum tensile strength of the cable can be obtained through data provided by the manufacturer, experimental testing, etc., and this application does not limit it.

[0109] In this embodiment, step 400, determining whether the target tension rod needs to be replaced based on the safe operating tension and the maximum wellhead tension, includes:

[0110] If the maximum wellhead tension is less than or equal to the safe operating tension, the target tension bar does not need to be replaced; if the maximum wellhead tension is greater than the safe operating tension, the target tension bar needs to be replaced.

[0111] Understandably, when the maximum wellhead tension is less than or equal to the safe operating tension, it indicates that the cable will not break when it encounters a jam. Therefore, in this case, there is no need to replace the current tension bar used to determine the maximum wellhead tension. However, when the maximum wellhead tension is greater than the safe operating tension, it indicates that the cable is at risk of breaking. In this case, a tension bar with a smaller maximum rated tensile force needs to be selected for logging operations to avoid cable breakage.

[0112] Step 500: If the target tension bar needs to be replaced, the selected new tension bar is replaced with the tension bar currently used to determine the maximum wellhead tension; wherein the maximum rated tension of the new tension bar is less than the maximum rated tension of the target tension bar.

[0113] Step 600: Determine the axial force at the current position of the locking point based on the maximum rated tensile force of the new tension bar, and return to execute step 200 until it is determined that the target tension bar does not need to be replaced.

[0114] Understandably, the wellhead tension at each target well depth is determined through iterative calculation based on the maximum rated tensile force of the pull rod. There is no definite conversion formula between the final determined maximum wellhead tension and the maximum rated tensile force of the pull rod used to calculate the maximum wellhead tension. Therefore, after determining that the pull rod needs to be replaced, it is necessary to perform iterative calculations based on the maximum rated tensile force of the selected new pull rod until it is determined that using the selected new pull rod will not cause the cable to break. Then, appropriate measures can be taken to avoid the problem of high retrieval costs caused by the cable breaking when the logging operation is stuck.

[0115] The following provides a specific example of a method for determining the maximum wellhead tension in an embodiment of this application.

[0116] The target well has a total well depth D of 2100m and a drilling fluid density ρ1 of 1300kg / m³. 3 When the logging instrument gets stuck, pulling has no effect. The pull rod reaches its maximum rated pulling force of 6000 lbf. At this time, the well depth position of the stuck point (i.e. the current position of the stuck point) d is 2100m.

[0117] The cable's outer diameter r is 11.8 mm, its weight in air m is 0.5 kg / m, the coefficient of friction between the cable and the well wall μ is 0.28, and the cable's maximum breaking force F... break The current is 89kN, and the cross-sectional area of ​​the cable is A=πr 2 / 4=0.00011m 2 The unit density ρ² = m / A = 4572.10 kg / m³ 3 Unit buoyancy F w =(ρ2-ρ1)×A×9.81=3.51N / m.

[0118] The wellbore trajectory is calculated using interpolation, where the well depth x at the interpolation point is represented by the well inclination angle α(x), the rate of change of the well inclination angle Δα(x), and the azimuth angle. and azimuth rate of change The results are obtained through calculations using the following formulas:

[0119] α(x)=cos -1 (cos[α i (x)]cos[τ(x)]-sin[α i (x)]cos[ω A (x)]sin[τ(x)])

[0120]

[0121]

[0122]

[0123] in:

[0124]

[0125]

[0126]

[0127]

[0128]

[0129]

[0130]

[0131]

[0132]

[0133]

[0134]

[0135] In the above formula, α i (x) and α i+1 (x) represents the inclination angle of the well at the interpolation point at well depth x, for the previous and next known points, respectively, ω. A ω(x) represents the initial tool face angle at the interpolation point depth x, ω(x) represents the instantaneous tool face angle at the interpolation point depth x, and τ(x) represents the radius angle at the interpolation point depth x. and Let R(x) represent the azimuth angles of the previous and next known points at the interpolation point depth x, respectively; let L(x) represent the radius of curvature at the interpolation point depth x; and let L(x) represent the well depth at the interpolation point. i (x) and L i+1 (x) represents the well depth of the previous and next known points at the well depth x of the interpolation point, respectively; γ(x) represents the full angle of the well depth x of the interpolation point.

[0136] The preset safety factor n is set to 1.25, and the preset micro-element Δl is set to 1m. The current position of the checkpoint is taken as the target position. At this time, the target well depth position sequence corresponding to the cable contains 2101 elements, where the well depth of the first element is 0m, i.e., the wellhead position, and the well depth of the last element is 2100m. The axial force F at the target position is... T (2100)=F L =6000lbf, i.e., F T (2100)=6000×4.45=26700N, the normal force F at the target location N The calculation process for (2100) (unit: N) is as follows:

[0137]

[0138] Taking the target position as the first position x, calculate the axial force F at the current second position (x = x - Δl = 2100 - 1 = 2099). T The calculation process for (2099) (unit: N) is as follows:

[0139] F T (2099)=F w ×cos[(2100)]+μ×F N (2100)+F T (2100)

[0140] = 3.51 × cos(17.436°) + 0.28 × 3.433 + 26700

[0141] =26704.31

[0142] Since the current second position x is not 0, the current second position is re-established as the first position, and the calculation is repeated until the current second position x = 0, to obtain the axial force and normal force corresponding to each target well depth when the target position is the current position of the checkpoint. Through iterative calculation, F is finally calculated. T (0) is 56.20 kN, which means the wellhead tension T(2100) = F when the well depth is 2100 meters. T (0) = 56.20 kN.

[0143] Since the currently calculated target well depth (i.e., the target position) is not the wellhead position, the target well depth position that is before and adjacent to the target position in the target well depth position sequence is replaced with the target position. Its axial force is set to the maximum rated tensile force of the tension rod, and the calculation is repeated to obtain the wellhead tension when the well depth is the new target position, until the wellhead tension of the wellhead position is determined, and finally the wellhead tension corresponding to each target well depth position in the target well depth position sequence is obtained.

[0144] Calculations show that the maximum wellhead tension T when the target well encounters a stuck condition is as follows: max =T(2100), therefore, with a preset safety factor n of 1.25, the safe operating tension F T,n = T(2100) / 1.25 = 71.2kN. Since T(2100) <F T,n Therefore, it can be assumed that when the target well gets stuck, using a tension bar with a maximum rated tensile force of 6000 lbf will not break the cable.

[0145] According to the maximum wellhead tension determination method provided in this embodiment, with the maximum rated tensile force of the tension rod being 6000 lbf, the wellhead tension of multiple wells at different well depths is calculated, and the results are as follows: Figure 5 As shown. Figure 5 The diagram illustrates the wellhead tension curve of an embodiment of this application. Figure 5 In the data, the maximum wellhead tensions for wells 1, 2, 3, and 4 are 56.20 kN, 50.11 kN, 64.75 kN, and 49.45 kN, respectively. According to... Figure 5 It can be seen that for any well, the greater the depth of the wellhead where the blockage point is located, the greater the corresponding maximum wellhead tension.

[0146] It is easy to see that the maximum wellhead tension determination method provided in this embodiment is based on the force analysis of the logging cable in the wellbore. By setting the current position of the stuck point as the first target position and setting the axial force at the target position as the maximum rated tensile force of the tension rod, the tension of the logging cable at the wellhead position at the target position is calculated iteratively first, that is, the wellhead tension at the target position. Then, the target position is replaced based on the target well depth position sequence, and the wellhead tension of the new target position is calculated iteratively until the wellhead tension of each target well depth position in the target well depth position sequence is calculated. This achieves high efficiency and high accuracy in determining the maximum wellhead tension without manual intervention, avoiding the need for professional technicians to roughly estimate the maximum wellhead tension when logging operations encounter stuck conditions. It also avoids the problems of cumbersome operation, slow speed and low accuracy. Relevant personnel can handle the corresponding issues based on the determined maximum wellhead tension, which can ensure the safety of logging equipment and operators, as well as the smooth progress of logging work.

[0147] Figure 1 This is a flowchart illustrating a method for determining maximum wellhead tension in one embodiment. It should be understood that, although... Figure 1 The steps in the flowchart are shown sequentially as indicated by the arrows, but these steps are not necessarily executed in the order indicated by the arrows. Unless otherwise explicitly stated herein, there is no strict order in which these steps are executed, and they can be performed in other orders. Figure 1 At least some of the steps in the process may include multiple sub-steps or multiple stages. These sub-steps or stages are not necessarily completed at the same time, but can be executed at different times. The execution order of these sub-steps or stages is not necessarily sequential, but can be executed in turn or alternately with other steps or at least some of the sub-steps or stages of other steps.

[0148] Figure 6 A schematic block diagram of the maximum wellhead tension determination device according to an embodiment of this application is shown. Figure 6 As shown, in one embodiment of this application, a maximum wellhead tension determination device is provided, including a position determination module, a wellhead tension determination module, and a maximum wellhead tension determination module, wherein:

[0149] The location determination module is used to determine the target well depth location sequence corresponding to the cable based on the current location of the jam point when the logging operation encounters a jam; wherein, the target well depth location sequence includes multiple target well depth locations.

[0150] The wellhead tension determination module is used to determine the wellhead tension at each target well depth position based on the axial force at the current position of the checkpoint.

[0151] The maximum wellhead tension determination module is used to determine the maximum wellhead tension based on the wellhead tension at each of the target well depth locations.

[0152] In this embodiment, the location determination module includes:

[0153] The segmentation submodule is used to divide the cable between the wellhead position and the current position of the checkpoint into multiple target micro-segments by using preset micro-segments.

[0154] The location generation submodule is used to generate the target well depth location sequence based on the endpoint values ​​of each target micro-segment within the corresponding well depth range.

[0155] In this embodiment, the wellhead tension determination module includes:

[0156] The target location determination submodule is used to take the current location of the checkpoint as the target location.

[0157] The first data calculation submodule is used to determine the axial force and normal force at the target location.

[0158] The second data calculation submodule is used to determine the wellhead tension at the target location based on the axial force and normal pressure at the target location.

[0159] The loop judgment submodule is used to replace the target well depth position that is before and adjacent to the target position in the target well depth position sequence with the target position, and return to execute the first data calculation submodule until the target position is determined to be the wellhead tension of the first element in the target well depth position sequence.

[0160] In this embodiment, the first data calculation submodule includes:

[0161] The axial force determination unit is used to determine the axial force at the target position based on the maximum rated tensile force of the tension bar.

[0162] The positive pressure calculation unit is used to determine the positive pressure at the target location according to a first formula, wherein the first formula is:

[0163]

[0164] Among them, F N (x) represents the positive pressure at the target location, where x represents the target location; F T (x) represents the axial force at the target location. Let α(x) represent the rate of change of the azimuth angle of the target location, α(x) represent the wellbore inclination angle of the target location, and Δα(x) represent the rate of change of the wellbore inclination angle of the target location. F w Δl represents the unit buoyancy of the cable, and Δl represents the length of the preset micro-segment of the cable.

[0165] In this embodiment, the second data calculation submodule includes:

[0166] A position determination unit is used to determine the target position as the first position.

[0167] The data calculation unit is used to take the target well depth position that is before and adjacent to the first position in the target well depth position sequence as the second position, determine the axial force and normal force of the second position based on the axial force and normal force of the first position, and replace the second position with the first position.

[0168] The loop judgment unit determines whether the first position is the first element in the target well depth position sequence. If it is, the axial force of the first element in the target well depth position sequence is determined as the wellhead tension of the target position. If not, it returns to the execution of the data calculation unit until the first position is the first element in the target well depth position sequence.

[0169] In this embodiment, the data calculation unit includes:

[0170] The axial force calculation subunit is used to determine the axial force at the second position according to the second formula, which is:

[0171] F T (x p ) = F w Δl cos[α(x p +Δl)]+μF N (x p +Δl)+F T (x p +Δl);

[0172] Among them, F T (x p ) represents the axial force at the second position, where x p Indicates the second position; F w α(x) represents the unit buoyancy of the cable, Δl represents the length of the preset micro-element segment of the cable, and α(x) represents the buoyancy of the cable. p +Δl) represents the rate of change of the well inclination angle at the first position, μ represents the coefficient of friction between the cable and the well wall, and F N (x p +Δl) represents the positive pressure at the first position, F T (x p +Δl) represents the axial force at the first position.

[0173] Optionally, the device further includes:

[0174] The tension comparison module uses the tension bar currently used to determine the maximum wellhead tension as the target tension bar, determines the safe operating tension based on the preset safety factor and the maximum wellhead tension, and determines whether the target tension bar needs to be replaced based on the safe operating tension and the maximum wellhead tension.

[0175] The tension bar selection module is used to replace the selected new tension bar with the current tension bar used to determine the maximum wellhead tension if the target tension bar needs to be replaced; wherein the maximum rated tension of the new tension bar is less than the maximum rated tension of the target tension bar.

[0176] The tension bar selection module is used to determine the axial force at the current position of the locking point based on the maximum rated tension of the new tension bar, and then return to execute the wellhead tension determination module until it is determined that the target tension bar does not need to be replaced.

[0177] In this embodiment, the maximum wellhead tension determination device includes a processor and a memory. The position determination module, the wellhead tension determination module, the wellhead tension determination module / and the tension comparison module / and the tension bar selection module are all stored as program units in the memory, and the processor executes the above-mentioned program modules stored in the memory to realize the corresponding functions.

[0178] The processor contains a kernel, which retrieves the corresponding program unit from memory. One or more kernels can be configured, and the method for determining the maximum wellhead tension described above can be implemented by adjusting the kernel parameters.

[0179] The memory may include non-permanent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one memory chip.

[0180] This application provides a processor configured to execute the above-described method for determining maximum wellhead tension.

[0181] This application provides a machine-readable storage medium storing instructions that, when executed by a processor, configure the processor to perform the above-described method for determining maximum wellhead tension.

[0182] Figure 7 The diagram schematically illustrates the internal structure of a computer device according to an embodiment of this application. Figure 7As shown, in one embodiment of this application, a computer device is provided, which can be a terminal. The computer device includes a processor A01, a network interface A02, a display screen A04, an input device A05, and a memory (not shown) connected via a system bus. The processor A01 provides computing and control capabilities. The memory includes internal memory A03 and a non-volatile storage medium A06. The non-volatile storage medium A06 stores an operating system B01 and a computer program B02. The internal memory A03 provides an environment for the operation of the operating system B01 and the computer program B02 stored in the non-volatile storage medium A06. The network interface A02 is used to communicate with an external terminal via a network connection. When the computer program is executed by the processor A01, it implements a method for determining maximum wellhead tension. The display screen A04 can be a liquid crystal display or an e-ink display. The input device A05 can be a touch layer covering the display screen, or buttons, a trackball, or a touchpad mounted on the computer device casing, or an external keyboard, touchpad, or mouse, etc.

[0183] Those skilled in the art will understand that Figure 7 The structure shown is merely a block diagram of a portion of the structure related to the present application and does not constitute a limitation on the computer device to which the present application is applied. Specific computer devices may include more or fewer components than those shown in the figure, or combine certain components, or have different component arrangements.

[0184] In one embodiment, the maximum wellhead tension determination device provided in this application can be implemented as a computer program, which can be configured as follows: Figure 7 The computer device shown runs on this device. The computer device's memory can store the various program modules that make up the maximum wellhead tension determination device, for example, Figure 6 The location determination module, the wellhead tension determination module, and the maximum wellhead tension determination module are shown. The computer program comprised of these modules causes the processor to execute the steps in the maximum wellhead tension determination methods of the various embodiments of this application described in this specification.

[0185] Figure 7 The computer device shown can be used as follows Figure 6 The position determination module in the maximum wellhead tension determination device shown executes step 100, the wellhead tension determination module executes step 200, and the maximum wellhead tension determination module executes step 300.

[0186] This application provides a device, which includes a processor, a memory, and a program stored in the memory and executable on the processor. When the processor executes the program, it performs the following steps:

[0187] Based on the current location of the jamming point when the well logging operation encounters a jam, determine the target well depth location sequence corresponding to the cable; wherein, the target well depth location sequence includes multiple target well depth locations.

[0188] Based on the axial force at the current location of the checkpoint, the wellhead tension at each of the target well depths is determined.

[0189] The maximum wellhead tension is determined based on the wellhead tension at each target well depth location.

[0190] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0191] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0192] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0193] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0194] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0195] Memory may include non-persistent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM. Memory is an example of computer-readable media.

[0196] Computer-readable media include both permanent and non-permanent, removable and non-removable media, which can store information using any method or technology. Information can be computer-readable instructions, data structures, modules of programs, or other data. Examples of computer storage media include, but are not limited to, phase-change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, CD-ROM, digital versatile optical disc (DVD) or other optical storage, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other non-transferable medium that can be used to store information accessible by a computing device. As defined herein, computer-readable media does not include transient computer-readable media, such as modulated data signals and carrier waves.

[0197] It should also be noted that 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 process, method, article, or apparatus. Unless otherwise specified, an element defined 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.

[0198] The above are merely embodiments of this application and are not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A method for determining maximum wellhead tension, characterized in that, include: Based on the current location of the jamming point when the well logging operation encounters a jam, determine the target well depth location sequence corresponding to the cable; wherein, the target well depth location sequence includes multiple target well depth locations; Based on the axial force at the current position of the checkpoint, determine the wellhead tension at each of the target well depths; The maximum wellhead tension is determined based on the wellhead tension at each target well depth location.

2. The method according to claim 1, characterized in that, The step of determining the target well depth position sequence corresponding to the cable based on the current location of the jamming point when encountering a jam during well logging operations includes: By pre-setting micro-segments, the cable between the wellhead location and the current location of the jamming point is divided into multiple target micro-segments; The target well depth position sequence is generated based on the endpoint values ​​of each target micro-segment within the corresponding well depth range.

3. The method according to claim 1, characterized in that, The determination of wellhead tension at each target well depth based on the axial force at the current position of the checkpoint includes: Use the current location of the checkpoint as the target location; Determine the axial force and normal force at the target location; Based on the axial force and normal force at the target location, determine the wellhead tension at the target location; Replace the target well depth position that is preceding and adjacent to the target position in the target well depth position sequence with the target position, and return to the step of determining the axial force and normal pressure of the target position until the wellhead tension of the first element in the target well depth position sequence is determined.

4. The method according to claim 3, characterized in that, The determination of the axial force and normal force at the target position includes: Determine the axial force at the target position based on the maximum rated tensile force of the tension bar; The normal force at the target location is determined according to the first formula, which is: Among them, F N (x) represents the positive pressure at the target location, where x represents the target location; F T (x) represents the axial force at the target location. Let α(x) represent the rate of change of the azimuth angle of the target location, α(x) represent the wellbore inclination angle of the target location, and Δα(x) represent the rate of change of the wellbore inclination angle of the target location. F w Δl represents the unit buoyancy of the cable, and Δl represents the length of the preset micro-segment of the cable.

5. The method according to claim 3, characterized in that, Determining the wellhead tension at the target location based on the axial force and normal force at the target location includes: The target location is taken as the first location; The target well depth position that is preceding and adjacent to the first position in the target well depth position sequence is taken as the second position. Based on the axial force and normal force at the first position, the axial force and normal force at the second position are determined, and the second position is replaced by the first position. Determine whether the first position is the first element in the target well depth position sequence. If yes, determine the axial force of the first element in the target well depth position sequence as the wellhead tension of the target position. If no, return to the step of taking the target well depth position in the target well depth position sequence that is before and adjacent to the first position as the second position, until the first position is the first element in the target well depth position sequence.

6. The method according to claim 5, characterized in that, The axial force at the second position is determined according to the second formula, which is: F T (x p )=F w Δlcos[α(x p +Δl)]+μF N (x p +Δl)+F T (x p +Δl); Among them, F T (x p ) represents the axial force at the second position, where x p Indicates the second position; F w α(x) represents the unit buoyancy of the cable, Δl represents the length of the preset micro-element segment of the cable, and α(x) represents the buoyancy of the cable. p +Δl) represents the rate of change of the well inclination angle at the first position, μ represents the coefficient of friction between the cable and the well wall, and F N (x p +Δl) represents the positive pressure at the first position, F T (x p +Δl) represents the axial force at the first position.

7. The method according to any one of claims 1 to 6, characterized in that, After determining the maximum wellhead tension based on the wellhead tension at each of the target well depth locations, the method further includes: The current tension bar used to determine the maximum wellhead tension is taken as the target tension bar. Based on the preset safety factor and the maximum wellhead tension, the safe operating tension is determined. Based on the safe operating tension and the maximum wellhead tension, it is determined whether the target tension bar needs to be replaced. If the target tension bar needs to be replaced, the selected new tension bar shall be replaced with the tension bar currently used to determine the maximum wellhead tension; wherein the maximum rated tension of the new tension bar is less than the maximum rated tension of the target tension bar; Based on the maximum rated tensile force of the new tension bar, determine the axial force at the current position of the jamming point, and return to execute the step of determining the wellhead tension at each target well depth position based on the axial force at the current position of the jamming point, until it is determined that the target tension bar does not need to be replaced.

8. A device for determining maximum wellhead tension, characterized in that, include: The location determination module is used to determine the target well depth location sequence corresponding to the cable based on the current location of the jamming point when the logging operation encounters a jam; wherein, the target well depth location sequence includes multiple target well depth locations; The wellhead tension determination module is used to determine the wellhead tension at each target well depth position based on the axial force at the current position of the checkpoint. The maximum wellhead tension determination module is used to determine the maximum wellhead tension based on the wellhead tension at each of the target well depth locations.

9. A processor, characterized in that, It is configured to perform the method for determining the maximum wellhead tension according to any one of claims 1 to 7.

10. A machine-readable storage medium storing instructions thereon, characterized in that, When executed by a processor, this instruction causes the processor to be configured to perform the method for determining the maximum wellhead tension according to any one of claims 1 to 7.

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