Tension prediction method, device and equipment for logging cable

Abstract

The invention discloses a tension prediction method, device and equipment for a logging cable, and relates to the technical field of logging, and the method comprises the steps: obtaining the calculation information of a to-be-logged well; calculating the upper tension of the instrument segment corresponding to the current to-be-predicted depth by using the calculation information; if the instrument section is not the wellhead vertical well section, taking the upper tension of the current well section as the lower tension of the previous well section, and calculating the tension value of the wellhead tensiometer corresponding to the current to-be-predicted depth by using calculation information according to the upper tension of the instrument section; by acquiring the calculation information of the to-be-measured well, the tension value at the wellhead tensiometer can be predicted according to the actual conditions of the to-be-measured well, the logging instrument and the cable, and the accuracy of tension prediction is improved; and a well section to be subjected to well logging is divided into a plurality of subsection well sections, upward calculation is conducted in sequence with the subsection well section where the prediction depth is located as a starting point, the tension value of a wellhead tensiometer is obtained, and automatic prediction of the tension of the well logging cable is achieved.

Description

Technical Field

[0001] The present invention relates to the field of well logging technology, and in particular to a method, device and equipment for predicting the tension of a well logging cable. Background Art

[0002] When logging equipment is stuck, the winch operator needs to rely on experience and short-term memory to judge the downhole situation and operate the winch to deal with it. The basis for judgment is the normal logging tension estimated by the manual approximate algorithm based on the vertical well model; the manual estimation based on the vertical well model approximate algorithm uses the vertical well as the calculation model. When the instrument depth unit is meter, the value of the depth divided by 2 is added to the value of the instrument weight in kilograms to obtain the value in kilograms; that is, T = deep / 2+mg. Among them, T is the wellhead cable tension, deep is the instrument depth, m is the instrument weight, and g is the acceleration of gravity. For example, if the instrument weight is 500 kg and the instrument depth is 3000 meters, then the estimated tension of the wellhead cable is: 3000 / 2+500=2000 kg; if the instrument weight is 400 kg and the instrument depth is 8000 meters, then the estimated tension of the wellhead cable is: 8000 / 2+400=4400 kg. This algorithm only takes into account the depth and instrument weight factors. It has high accuracy in vertical wells. However, in highly deviated wells, factors such as the friction of the well wall on the cable cannot be ignored. The deviation of its calculation results can reach 15-30%, which can no longer truly reflect the downhole conditions. In some wells, the deviation can even reach 50%, which has no practical application value.

[0003] Therefore, how to accurately and automatically predict the logging cable tension and improve user experience is an urgent problem to be solved today. Summary of the invention

[0004] The purpose of the present invention is to provide a method, device and equipment for predicting the tension of a logging cable, so as to accurately and automatically predict the tension of the logging cable and improve the user experience.

[0005] In order to solve the above technical problems, the present invention provides a method for predicting the tension of a logging cable, comprising:

[0006] Acquire calculation information of the well to be logged; wherein the calculation information includes well information of the well to be logged and model information of the logging instrument and the cable, and the well information includes well depth, well inclination, azimuth, mud viscosity and mud density;

[0007] Divide the well section to be tested into a plurality of segmented well sections; wherein the segmented well sections include a wellhead vertical well section and a well deviation well section;

[0008] Utilizing the calculation information, the upper tension of the instrument segment corresponding to the current depth to be predicted is calculated; wherein the instrument segment is a segmented well section where the logging instrument is located; wherein the current depth to be predicted is any depth to be predicted;

[0009] If the instrument segment is not the wellhead vertical well segment, the upper tension of the current well segment is used as the lower tension of the previous well segment, and the tension value at the wellhead tension meter corresponding to the current predicted depth is calculated based on the upper tension of the instrument segment and the calculation information; wherein the tension value is the upper tension of the wellhead vertical well segment, the current well segment is any of the well inclination segments, the previous well segment is the current well segment, and the first segmented well segment above the current well segment.

[0010] Optionally, dividing the well section to be tested into a plurality of segmented well sections includes:

[0011] According to the preset well section length, the well section of the well to be tested is divided into a plurality of segmented well sections.

[0012] Optionally, when the current depth to be predicted is the uppermost depth of any of the segmented well sections, the calculating the upper tension of the instrument segment corresponding to the current depth to be predicted by using the calculation information includes:

[0013] Using the calculation information, the well inclination of the segmented well section corresponding to the current predicted depth and the first force information corresponding to the logging instrument are obtained; wherein the first force information includes instrument buoyancy, instrument gravity, side pressure friction, mud additional friction and open leg additional friction;

[0014] The upper tension of the instrument segment corresponding to the current depth to be predicted is calculated based on the well inclination of the segmented well section corresponding to the current depth to be predicted and the first force information.

[0015] Optionally, the calculating the upper tension of the instrument segment corresponding to the current depth to be predicted according to the well inclination of the segmented well section corresponding to the current depth to be predicted and the first force information includes:

[0016] The upper tension of the instrument segment corresponding to the current depth to be predicted is calculated by T1=mg*cos(dev)+(mg-pgv)*sin(dev)*u+f1+f2; wherein T1 is the upper tension of the instrument segment corresponding to the current depth to be predicted, mg is the instrument gravity, dev is the well inclination of the segmented well section corresponding to the current depth to be predicted, pgv is the instrument buoyancy, (mg-pgv)*sin(dev)*u is the side pressure friction, f1 is the mud additional friction, and f2 is the open leg additional friction.

[0017] Optionally, the upper tension of the current well section is used as the lower tension of the previous well section, and according to the upper tension of the instrument segment, the tension value at the wellhead tension meter corresponding to the current depth to be predicted is calculated using the calculation information, including:

[0018] Determine the segmented well section corresponding to the current depth to be predicted as the current well section;

[0019] Using the upper tension of the current well section as the lower tension of the previous well section, and calculating the upper tension of the previous well section based on the lower tension of the previous well section and using the calculation information;

[0020] Determine whether the previous well section is the wellhead vertical well section;

[0021] If yes, the upper tension of the previous well section is determined as the tension value at the wellhead tension gauge corresponding to the current depth to be predicted;

[0022] If not, the previous well section is determined as the current well section, and the step of using the upper tension of the current well section as the lower tension of the previous well section and calculating the upper tension of the previous well section based on the lower tension of the previous well section and using the calculation information is executed.

[0023] Optionally, the calculating the upper tension of the previous well section according to the lower tension of the previous well section by using the calculation information includes:

[0024] Using the calculation information, obtain the well inclination of the previous well section, the solid angle corresponding to the dogleg degree and the second force information corresponding to the cable in the previous well section; wherein the second force information includes the cable buoyancy, the cable gravity, the cable side pressure friction and the cable mud additional friction;

[0025] The upper tension of the previous well section is calculated based on the well inclination and the solid angle corresponding to the dogleg degree of the previous well section, the second force information and the lower tension of the previous well section.

[0026] Optionally, the method further includes:

[0027] A depth-tension curve is generated based on the tension values ​​at the wellhead tension meter corresponding to each of the depths to be predicted.

[0028] Optionally, before using the calculation information to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted, the method further includes:

[0029] The maximum depth to be predicted is determined as the current depth to be predicted, and the step of using the calculation information to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted is performed;

[0030] Correspondingly, after taking the upper tension of the current well section as the lower tension of the previous well section, and calculating the tension value at the wellhead tension meter corresponding to the current depth to be predicted according to the upper tension of the instrument segment and using the calculation information, the method further includes:

[0031] Determine whether the current depth to be predicted is the minimum depth to be predicted;

[0032] If yes, then executing the step of drawing and generating a depth-tension curve according to the tension values ​​at the wellhead tension gauges corresponding to the respective depths to be predicted;

[0033] If not, the last depth to be predicted corresponding to the current depth to be predicted is determined as the current depth to be predicted, and the step of using the calculation information to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted is performed.

[0034] The present invention also provides a tension prediction device for a logging cable, comprising:

[0035] An information acquisition module is used to acquire calculation information of the well to be logged; wherein the calculation information includes well information of the well to be logged and model information of the logging instrument and the cable, and the well information includes well depth, well inclination, azimuth, mud viscosity and mud density;

[0036] A well section division module is used to divide the well section of the well to be measured into multiple segmented well sections; wherein the segmented well sections include a wellhead vertical well section and a well deviation well section;

[0037] An instrument calculation module, used to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted using the calculation information; wherein the instrument segment is a segmented well section where the logging instrument is located; wherein the current depth to be predicted is any depth to be predicted;

[0038] A cable calculation module is used to, if the instrument segment is not the wellhead vertical well segment, use the upper tension of the current well segment as the lower tension of the previous well segment, and calculate the tension value at the wellhead tension meter corresponding to the current predicted depth based on the upper tension of the instrument segment and the calculation information; wherein the tension value is the upper tension of the wellhead vertical well segment, the current well segment is any of the well deviated segments, and the previous well segment is the current well segment, which is the first segmented well segment above the current well segment.

[0039] The present invention also provides a tension prediction device for a logging cable, comprising:

[0040] Memory for storing computer programs;

[0041] A processor is used to implement the steps of the method for predicting the tension of a logging cable as described above when executing the computer program.

[0042] The present invention provides a method for predicting the tension of a logging cable, comprising: obtaining calculation information of a well to be logged; wherein the calculation information comprises well information of the well to be logged and model information of a logging instrument and a cable, and the well information comprises well depth, well deviation, azimuth, mud viscosity and mud density; dividing the well section of the well to be logged into a plurality of segmented well sections; wherein the segmented well sections comprise a wellhead vertical well section and a well deviation well section; using the calculation information, calculating the upper tension of the instrument segment corresponding to the current depth to be predicted; wherein the instrument segment is A segmented well section where the logging instrument is located; wherein the current depth to be predicted is any depth to be predicted; if the instrument segment is not a wellhead vertical well section, the upper tension of the current well section is used as the lower tension of the previous well section, and according to the upper tension of the instrument segment, the tension value at the wellhead tension meter corresponding to the current depth to be predicted is calculated using the calculation information; wherein the tension value is the upper tension of the wellhead vertical well section, the current well section is any well deviated well section, the previous well section is the current well section, and the first segmented well section above the current well section;

[0043] It can be seen that the present invention can predict the tension value at the wellhead tension meter according to the actual conditions of the well to be measured, the logging instrument and the cable by obtaining the calculation information of the well to be measured, thereby improving the accuracy of the tension prediction; and by dividing the well section of the well to be measured into multiple segmented well sections, starting from the segmented well section where the predicted depth is located and calculating upward in sequence, the tension value at the wellhead tension meter is obtained, thereby realizing the automatic prediction of the tension of the logging cable and improving the user experience. In addition, the present invention also provides a tension prediction device and equipment for logging cables, which also have the above-mentioned beneficial effects. BRIEF DESCRIPTION OF THE DRAWINGS

[0044] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on the provided drawings without paying creative work.

[0045] Figure 1 A flow chart of a method for predicting the tension of a logging cable provided in an embodiment of the present invention;

[0046] Figure 2 A schematic diagram of force analysis of a logging instrument for another method for predicting the tension of a logging cable provided by an embodiment of the present invention;

[0047] Figure 3 A schematic diagram of cable force analysis for another method for predicting the tension of a logging cable provided by an embodiment of the present invention;

[0048] Figure 4A schematic diagram of a cyclic calculation of another method for predicting the tension of a logging cable provided by an embodiment of the present invention;

[0049] Figure 5 A schematic diagram of the tension transmission and instrument operation process of another method for predicting the tension of a logging cable provided by an embodiment of the present invention;

[0050] Figure 6 A structural block diagram of a tension prediction device for a logging cable provided in an embodiment of the present invention;

[0051] Figure 7 A schematic structural diagram of a tension prediction device for a logging cable provided in an embodiment of the present invention;

[0052] Figure 8 A schematic diagram of the specific structure of a tension prediction device for a logging cable provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0053] In order to make the purpose, technical solution and advantages of the embodiments of the present invention clearer, the technical solution in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0054] Please refer to Figure 1 , Figure 1 A flow chart of a method for predicting the tension of a logging cable provided in an embodiment of the present invention. The method may include:

[0055] Step 101: Obtain calculation information of the well to be measured; wherein the calculation information includes well information of the well to be measured and model information of the logging instrument and the cable, and the well information includes well depth, well inclination, azimuth, mud viscosity and mud density.

[0056] It is understandable that the well to be logged in this step may be a well that needs to be logged using a logging instrument. The calculation information of the well to be logged in this step may be information required for predicting and calculating the tension of the logging cable corresponding to the well to be logged, that is, information of the well to be logged, the logging instrument and the cable.

[0057] Specifically, the specific content of the calculation information for the well to be logged in this embodiment can be set by the designer according to the usage scenario and user needs. For example, the calculation information can include well information of the well to be logged related to the actual situation of the well to be logged and model information of the logging instrument and cable related to the actual situation of the logging instrument and cable. For example, the above-mentioned well information may include information such as well depth, well inclination and azimuth obtained by analyzing the well inclination and azimuth data file. The well inclination and azimuth data file can provide the drilling team or directional team with data describing the wellbore structure (multi-point data) before logging, which generally includes data such as well depth, well inclination and azimuth; the well information may also include information such as casing program, casing depth, well depth, mud viscosity and mud density obtained by analyzing the well information table. The well information table can be a table that the drilling team will use to provide the well information to be logged, which generally includes data such as casing program, casing depth, well depth, mud viscosity and mud density; the well information may also include the well inclination, azimuth and depth obtained by analyzing the well inclination and azimuth data file, and the vertical depth, displacement, dogleg, solid angle, well inclination change rate and azimuth change rate of each depth calculated; that is, the processor can obtain the well information of the well to be logged by parsing the well inclination and azimuth data file and the well information table. The above-mentioned model information may be information obtained by the processor parsing the model of the logging instrument and the cable, such as the weight (mass) of the logging instrument, the unit weight and unit volume of the cable, etc. The model structure of the logging instrument and the cable may be that the bottom end is the logging instrument, which may be located at the top end of a certain segmented well section, and the cable is located above all segmented well sections above the logging instrument. As long as the processor can obtain the data related to the actual situation of the well to be logged, the logging instrument and the cable required for predicting and calculating the logging cable tension corresponding to the well to be logged, this embodiment does not impose any restrictions on this.

[0058] Step 102: Divide the well section to be tested into a plurality of segmented well sections; wherein the segmented well sections include a wellhead vertical well section and a well deviation well section.

[0059] It can be understood that the segmented well sections in this step can be the well sections obtained by dividing the well section to be measured, that is, all the segmented well sections can constitute the well section to be measured. The wellhead vertical well section in this step can be the well section without well deviation data (straight well) at the wellhead, and the well deviation well section in this step can be the segmented well sections below the wellhead vertical well section.

[0060] Specifically, the specific manner in which the processor divides the well section to be measured into multiple segmented well sections in this step can be set by the designer according to practical scenarios and user needs. For example, the processor can divide the well section of the well to be measured into multiple segmented well sections according to a preset well section length (such as using a multi-point data depth interval, such as 25 meters); for example, the processor can directly start from the wellhead or the bottom of the well to be measured, and divide the well section of the well to be measured into multiple segmented well sections according to the preset well section length; the processor can also start from the wellhead of the well to be measured, determine the well section where the well inclination is not detected as the wellhead straight well section, and after the well inclination is detected, divide the remaining well section into one or more well inclination well sections by the preset well section length. The processor can also divide the well section of the well to be measured into a preset number of segmented well sections, such as evenly dividing the well section of the well to be measured into a preset number of segmented well sections according to a preset number. This embodiment does not impose any restrictions on this.

[0061] Step 103: Calculate the upper tension of the instrument segment corresponding to the current depth to be predicted using the calculation information; wherein the instrument segment is a segmented well section where the logging instrument is located; wherein the current depth to be predicted is any depth to be predicted.

[0062] It is understandable that the current depth to be predicted in this step can be any depth to be predicted, that is, the depth to be predicted. The instrument segment corresponding to the current depth to be predicted in this step can be the segmented well section where the logging instrument is located when the logging instrument is at the current depth to be predicted of the well to be logged.

[0063] Specifically, this embodiment is demonstrated by taking the prediction of the logging cable tension (i.e., the tension value at the wellhead tension meter) when the logging instrument is at a depth of the well to be logged (i.e., the current predicted depth) as an example; for the prediction of the logging cable tension when the logging instrument is at other depths of the well to be logged, it can be achieved in the same or similar manner as the method provided in this embodiment, and this embodiment does not impose any limitation on this.

[0064] Specifically, the specific method for the processor in this step to use the calculation information to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted can be set by the designer according to practical scenarios and user needs. For example, when the current depth to be predicted is the uppermost depth of any segmented well section, the force condition of the logging instrument can be as follows: Figure 2As shown, including instrument buoyancy (pgv), instrument gravity (mg), cable tension (T1, i.e., upper tension), lateral pressure (N), lateral pressure friction (f), mud additional friction (f1) and open leg additional friction (f2), the processor can use the calculation information to obtain the well inclination of the segmented well section corresponding to the current predicted depth and the first force information corresponding to the logging instrument; wherein the first force information includes instrument buoyancy, instrument gravity, lateral pressure friction, mud additional friction and open leg additional friction; according to the well inclination of the segmented well section corresponding to the current predicted depth and the first force information, the upper tension of the instrument segment corresponding to the current predicted depth is calculated, such as by Figure 2 As shown in FIG. 1, T1=mg*cos(dev)+(mg-pgv)*sin(dev)*u+f1+f2 is used to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted; wherein T1 is the upper tension of the instrument segment corresponding to the current depth to be predicted, mg is the instrument gravity, dev is the well inclination of the segmented well section corresponding to the current depth to be predicted, pgv is the instrument buoyancy, (mg-pgv)*sin(dev)*u is the side pressure friction, f1 is the additional friction of the mud, and f2 is the additional friction of the opening leg; wherein the processor can calculate the instrument buoyancy according to the volume (v) of the logging instrument in the model information and the mud density (p) in the well information; according to the model The weight (m) of the logging instrument in the model information is used to calculate the instrument gravity; the side pressure friction force (f) is calculated according to the instrument gravity, the instrument buoyancy, the well inclination (dev) of the segmented well section corresponding to the current predicted depth and the well wall friction coefficient (u) in the well information, that is, f=Nu=(mg-pgv)*sin(dev)*u; the mud additional friction force (f1) is calculated according to the instrument movement speed in the model information and the mud viscosity and wellbore inner diameter in the well information, or the first preset friction force in the well information is determined as the mud additional friction force; the open leg additional friction force is calculated according to the instrument mechanical structure information in the model information, or the second preset friction force in the well information is determined as the open leg additional friction force.

[0065] Step 104: If the instrument segment is not a vertical well section at the wellhead, the upper tension of the current well section is used as the lower tension of the previous well section. According to the upper tension of the instrument segment, the tension value at the wellhead tension meter corresponding to the current predicted depth is calculated using the calculation information; wherein the tension value is the upper tension of the vertical well section at the wellhead, the current well section is any well inclination section, the previous well section is the current well section, and the first segmented well section above the current well section.

[0066] It is understandable that in this step, when the instrument segment corresponding to the current predicted depth is not a vertical well segment at the wellhead, the processor can use the upper tension of the current well segment as the lower tension of the previous well segment (i.e., the previous well segment) to cycle with the instrument segment as the starting point (e.g., Figure 4The inner loop shown in the figure calculates the upper tension toward the upper well section until the upper tension of the vertical well section at the wellhead is calculated as the tension value at the wellhead tension meter.

[0067] Correspondingly, in this step, the processor uses the upper tension of the current well section as the lower tension of the previous well section, and uses the calculation information to calculate the tension value at the wellhead tension meter corresponding to the current depth to be predicted according to the upper tension of the instrument segment, that is, the upper tension of the current well section is used as the lower tension of the previous well section, and the specific method of cyclically calculating the upper tension of the previous well section can be set by the designer. For example, the processor can determine the segmented well section corresponding to the current depth to be predicted as the current well section; the upper tension of the current well section As the lower tension of the previous well section, according to the lower tension of the previous well section, using the calculation information, calculate the upper tension of the previous well section; determine whether the previous well section is a wellhead vertical well section; if so, determine the upper tension of the previous well section as the tension value at the wellhead tension meter corresponding to the current predicted depth; if not, determine the previous well section as the current well section, and execute the steps of using the upper tension of the current well section as the lower tension of the previous well section, and according to the lower tension of the previous well section, using the calculation information, calculate the upper tension of the previous well section.

[0068] Specifically, the specific method for the processor to calculate the upper tension of the previous well section based on the lower tension of the previous well section using the calculation information, that is, the specific method for calculating the upper tension of the previous well section using the upper tension of the current well section, can be set by the designer. For example, the stress condition of the cable in the previous well section can be as follows: Figure 3 As shown in FIG. 1 , including cable buoyancy (pgv), cable gravity (mg), upper cable tension (T2, i.e., the upper tension of the previous well section), cable side pressure (N), cable side pressure friction (f), cable mud additional friction (f1) and lower cable tension (i.e., the lower tension of the previous well section), the processor can use the calculation information to obtain the well inclination of the previous well section (such as Figure 3 Dev in), the solid angle corresponding to the dogleg degree (such as Figure 3 a) in the figure and the second force information corresponding to the cable in the previous well section; wherein the second force information includes the buoyancy of the cable, the gravity of the cable, the side pressure friction of the cable and the additional friction of the cable mud; the upper tension of the previous well section is calculated according to the solid angle corresponding to the well inclination and the dogleg degree of the previous well section, the second force information and the lower tension of the previous well section.

[0069] It is understandable that if Figure 4 and Figure 5As shown, in this embodiment, the processor can predict the tension value of the wellhead cable tension sensor (i.e., the wellhead tension meter) when the logging instrument is at various depths (i.e., the depth to be measured) in the entire well section to be measured. For any depth of the logging instrument that needs to be predicted (i.e., the depth to be measured), the force calculation can be started from the segmented well section (i.e., the instrument well section) where the logging instrument is located, and the upper cable tension (i.e., the upper tension of the previous well section) can be obtained. Then, the cycle calculation (i.e., the inner cycle) of each upper segmented well section can be started, and the calculation is looped until the cable tension at the wellhead, i.e., the tension value at the wellhead tension meter; that is, the first calculation of the inner cycle calculation calculates the tension of the cable of the first segmented well section length at the top of the logging instrument, which is used as the lower tension of the first calculation of the segmented well section where the cable is located; the second calculation of the inner cycle calculation uses the result of the previous cycle calculation as the current calculation result. The calculated lower tension is used to calculate the cable tension on the upper part of the cable in this segmented well section; the third calculation of the inner loop calculation uses the result of the second calculation as the lower tension, and the cycle is repeated to calculate the upper tension of all segmented cables; the last calculation in the inner loop is to calculate the cable without well inclination data (i.e., the wellhead vertical well section) at the top. This section is considered to have zero well inclination and zero dogleg degree, and the cable tension at the wellhead is calculated; at the end of this inner loop, the cable tension at the wellhead when the logging instrument is at a certain depth is obtained; based on the above results, a set of depth (i.e., the depth to be predicted) and corresponding tension value data can be obtained, which can be used as one of the points in depicting the depth-tension curve.

[0070] Correspondingly, the method provided in this embodiment may also include an outer loop corresponding to each depth to be predicted, that is, the processor may cyclically calculate the tension value at the wellhead tension meter corresponding to each depth to be predicted, so as to obtain the tension value at the wellhead tension meter corresponding to each depth to be predicted; Figure 4 and Figure 5As shown, the processor can cyclically calculate the tension value at the wellhead tension meter corresponding to each depth to be predicted from bottom to top (ie, from large to small depth). For example, the first calculation of the outer loop can calculate the predicted depth of the logging instrument at the bottom of the well to be logged (such as the bottom hole depth or the top depth of the lowest segmented well section), and execute steps 103 and 104 once to obtain the tension value at the wellhead tension meter corresponding to the predicted depth; the first calculation of the outer loop can calculate the predicted depth of the logging instrument at the second deepest depth, and execute steps 103 and 104 once to obtain the tension value at the wellhead tension meter corresponding to the predicted depth; the outer loop is analogous, and the calculation is continued until the logging instrument reaches the segmented well section without well deviation (that is, the wellhead vertical well section); the last calculation of the outer loop calculates the tension value at the wellhead tension meter corresponding to the predicted depth of the logging instrument at the wellhead vertical well section (such as the bottom and / or top depth of the wellhead vertical well section), and obtains the tension values ​​at the wellhead tension meters corresponding to all the predicted depths, and further the data points of all the predicted depths-tension values ​​can be plotted as a depth-tension curve to facilitate subsequent query use.

[0071] That is to say, in order to facilitate the prediction of the tension value at the wellhead tension meter corresponding to each depth to be predicted, the depth to be predicted in this embodiment may include the depth of the uppermost end of each well inclination section or the depth of the uppermost end of each segmented well section, so as to reduce the influence of the cable on the calculation of the upper tension of the instrument segment; correspondingly, the depth to be predicted may also include other depths in the segmented well section, that is, the calculation of the upper tension of the instrument segment may also include the force of the cable in the instrument segment, and adopt the same method as Figure 2 and Figure 3 Similar force analysis methods are used for corresponding calculations, and this embodiment does not impose any limitation on this.

[0072] Correspondingly, in this embodiment, after obtaining the tension values ​​at the wellhead tension gauge corresponding to each depth to be predicted, the processor can also draw and generate a depth-tension curve according to the tension values ​​at the wellhead tension gauge corresponding to each depth to be predicted; that is, the processor can use the tension values ​​at the wellhead tension gauge corresponding to all the depths to be predicted to draw and generate a corresponding curve (i.e., depth-tension curve) between the depth to be predicted and the corresponding tension value, to facilitate subsequent query calls.

[0073] Specifically, the specific calculation method of the tension value at the wellhead tension meter corresponding to each depth to be predicted in this embodiment can be set by the designer according to the practical scenario and user needs. For example, the tension value corresponding to each depth to be predicted can be calculated cyclically, such as using Figure 4 and Figure 5The depth shown is cyclically calculated in a decreasing depth-to-depth loop (external loop) manner, and the tension value at the wellhead tension meter corresponding to each depth to be predicted is cyclically calculated; for example, the processor may determine the maximum depth to be predicted as the current depth to be predicted before step 103, and then enter step 103; correspondingly, after step 104, determine whether the current depth to be predicted is the minimum depth to be predicted; if not, enter step 103; if so, the tension value at the wellhead tension meter corresponding to all the depths to be predicted is obtained, and the tension value at the wellhead tension meter corresponding to each depth to be predicted can be further used to draw and generate a depth-tension curve.

[0074] In this embodiment, the embodiment of the present invention can predict the tension value at the wellhead tension meter according to the actual conditions of the well to be measured, the logging instrument and the cable by acquiring the calculation information of the well to be measured, thereby improving the accuracy of the tension prediction; and by dividing the well section of the well to be measured into multiple segmented well sections, starting from the segmented well section where the predicted depth is located and calculating upward in sequence, the tension value at the wellhead tension meter is obtained, thereby realizing automatic prediction of the logging cable tension and improving the user experience.

[0075] Corresponding to the above method embodiment, the embodiment of the present invention further provides a logging cable tension prediction device. The logging cable tension prediction device described below and the logging cable tension prediction method described above can refer to each other.

[0076] Please refer to Figure 6 , Figure 6 This is a structural block diagram of a tension prediction device for a logging cable provided by an embodiment of the present invention. The device may include:

[0077] The information acquisition module 10 is used to acquire the calculation information of the well to be logged; wherein the calculation information includes the well information of the well to be logged and the model information of the logging instrument and the cable, and the well information includes the well depth, well deviation, azimuth, mud viscosity and mud density;

[0078] The well section division module 20 is used to divide the well section of the well to be measured into a plurality of segmented well sections; wherein the segmented well sections include a wellhead vertical well section and a well deviation well section;

[0079] The instrument calculation module 30 is used to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted using the calculation information; wherein the instrument segment is a segmented well section where the logging instrument is located; wherein the current depth to be predicted is any depth to be predicted;

[0080] The cable calculation module 40 is used to use the upper tension of the current well section as the lower tension of the previous well section if the instrument segment is not a wellhead vertical well section, and calculate the tension value at the wellhead tension meter corresponding to the current predicted depth based on the upper tension of the instrument segment and the calculation information; wherein the tension value is the upper tension of the wellhead vertical well section, the current well section is any well inclination section, the previous well section is the current well section, and the first segmented well section above the current well section.

[0081] Optionally, the well section division module 20 may be specifically used to divide the well section of the well to be measured into a plurality of segmented well sections according to a preset well section length.

[0082] Optionally, when the current depth to be predicted is the uppermost depth of any segmented well section, the instrument calculation module 30 may include:

[0083] The force acquisition submodule is used to obtain the well inclination of the segmented well section corresponding to the current predicted depth and the first force information corresponding to the logging instrument by using the calculation information; wherein the first force information includes the instrument buoyancy, the instrument gravity, the side pressure friction, the mud additional friction and the opening leg additional friction;

[0084] The tension calculation submodule is used to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted based on the well inclination and the first force information of the segmented well section corresponding to the current depth to be predicted.

[0085] Optionally, the first tension calculation submodule can be specifically used to calculate the upper tension of the instrument segment corresponding to the current predicted depth through T1=mg*cos(dev)+(mg-pgv)*sin(dev)*u+f1+f2; wherein T1 is the upper tension of the instrument segment corresponding to the current predicted depth, mg is the instrument gravity, dev is the well inclination of the segmented well section corresponding to the current predicted depth, pgv is the instrument buoyancy, (mg-pgv)*sin(dev)*u is the side pressure friction, f1 is the additional friction of the mud, and f2 is the additional friction of the opening leg.

[0086] Optionally, the cable calculation module 40 may include:

[0087] The first determination submodule is used to determine the segmented well section corresponding to the current depth to be predicted as the current well section;

[0088] The first calculation submodule is used to use the upper tension of the current well section as the lower tension of the previous well section, and calculate the upper tension of the previous well section based on the lower tension of the previous well section and using the calculation information;

[0089] The inner loop judgment submodule is used to judge whether the previous well section is a wellhead vertical well section;

[0090] The second determination submodule is used to determine the upper tension of the previous well section as the tension value at the wellhead tension meter corresponding to the current depth to be predicted if it is a wellhead vertical well section;

[0091] The third determination submodule is used to determine the previous well section as the current well section if the well section is a vertical well section at the wellhead, and send a start signal to the first calculation submodule.

[0092] The optional first calculation submodule may include:

[0093] A force acquisition unit is used to obtain the well inclination of the previous well section, the solid angle corresponding to the dogleg degree and the second force information corresponding to the cable in the previous well section by using the calculation information; wherein the second force information includes the cable buoyancy, the cable gravity, the cable side pressure friction and the cable mud additional friction;

[0094] The tension calculation unit is used to calculate the upper tension of the previous well section according to the well inclination and the solid angle corresponding to the dogleg degree of the previous well section, the second force information and the lower tension of the previous well section.

[0095] Optionally, the device may further include:

[0096] The line drawing module is used to draw and generate a depth-tension curve according to the tension value at the wellhead tension meter corresponding to each depth to be predicted.

[0097] Optionally, the device may further include:

[0098] The outer loop start module is used to determine the maximum depth to be predicted as the current depth to be predicted, and the instrument calculation module 30 sends a start signal;

[0099] Correspondingly, the upper tension of the current well section is used as the lower tension of the previous well section, and after calculating the tension value at the wellhead tension meter corresponding to the current depth to be predicted using the calculation information according to the upper tension of the instrument segment, the method further includes:

[0100] The outer loop judgment module is used to judge whether the current depth to be predicted is the minimum depth to be predicted after calculating the tension value at the wellhead tension meter corresponding to the current depth to be predicted; if so, a start signal is sent to the line drawing module; if not, the previous depth to be predicted corresponding to the current depth to be predicted is determined as the current depth to be predicted, and a start signal is sent to the instrument calculation module 30.

[0101] In this embodiment, the embodiment of the present invention obtains the calculation information of the well to be measured through the information acquisition module 10, and can predict the tension value at the wellhead tension meter according to the actual conditions of the well to be measured, the logging instrument and the cable, thereby improving the accuracy of the tension prediction; and the well section of the well to be measured is divided into multiple segmented well sections through the well section division module 20, and the segmented well section where the predicted depth is located is used as the starting point to calculate upward in sequence to obtain the tension value at the wellhead tension meter, thereby realizing automatic prediction of the logging cable tension and improving the user experience.

[0102] Corresponding to the above method embodiment, the embodiment of the present invention further provides a logging cable tension prediction device. The logging cable tension prediction device described below and the logging cable tension prediction method described above can refer to each other.

[0103] Please refer to Figure 7 , Figure 7 A structural schematic diagram of a tension prediction device for a logging cable provided in an embodiment of the present invention. The tension prediction device for a logging cable may include:

[0104] A memory D1, for storing computer programs;

[0105] The processor D2 is used to implement the steps of the method for predicting the tension of the logging cable provided in the above method embodiment when executing the computer program.

[0106] For details, please refer to Figure 8 , Figure 8 A schematic diagram of the specific structure of a tension prediction device for a logging cable provided in an embodiment of the present invention. The tension prediction device 310 may have relatively large differences due to different configurations or performances, and may include one or more processors (central processing units, CPU) 322 (for example, one or more processors) and a memory 332, and one or more storage media 330 (for example, one or more mass storage devices) storing application programs 342 or data 344. Among them, the memory 332 and the storage medium 330 may be temporary storage or permanent storage. The program stored in the storage medium 330 may include one or more modules (not shown in the figure), and each module may include a series of instruction operations in the data processing device. Furthermore, the central processor 322 may be configured to communicate with the storage medium 330 to execute a series of instruction operations in the storage medium 330 on the tension prediction device 310.

[0107] The tension prediction device 310 may further include one or more power supplies 326, one or more wired or wireless network interfaces 350, one or more input and output interfaces 358, and / or one or more operating systems 341. For example, Windows Server™, Mac OS X™, Unix™, Linux™, FreeBSD™, etc.

[0108] The tension prediction device 310 may specifically be a server or a computer terminal.

[0109] The steps in the cable tension prediction method described above can be implemented by the structure of the logging cable tension prediction device.

[0110] Corresponding to the above method embodiment, the embodiment of the present invention further provides a readable storage medium. The readable storage medium described below and the tension prediction method of a logging cable described above can refer to each other.

[0111] A readable storage medium stores a computer program, and when the computer program is executed by a processor, the steps of the method for predicting the tension of a logging cable provided in the above method embodiment are implemented.

[0112] The readable storage medium may specifically be a U disk, a mobile hard disk, a read-only memory (ROM), a random access memory (RAM), a magnetic disk or an optical disk, or other readable storage medium that can store program codes.

[0113] The various embodiments in the specification are described in a progressive manner, and each embodiment focuses on the differences from other embodiments. The same or similar parts between the various embodiments can be referred to each other. For the devices, equipment and readable storage media disclosed in the embodiments, since they correspond to the methods disclosed in the embodiments, the description is relatively simple, and the relevant parts can be referred to the method part description.

[0114] The above is a detailed introduction to the method, device and equipment for predicting the tension of a logging cable provided by the present invention. This article uses specific examples to illustrate the principles and implementation methods of the present invention. The description of the above embodiments is only used to help understand the method and core ideas of the present invention. It should be pointed out that for ordinary technicians in this technical field, without departing from the principles of the present invention, the present invention can also be improved and modified in a number of ways, and these improvements and modifications also fall within the scope of protection of the claims of the present invention.

Claims

1. A method for predicting the tension of a logging cable, characterized in that: include: Acquire calculation information of the well to be logged; wherein the calculation information includes well information of the well to be logged and model information of the logging instrument and the cable, and the well information includes well depth, well inclination, azimuth, mud viscosity and mud density; Divide the well section to be tested into a plurality of segmented well sections; wherein the segmented well sections include a wellhead vertical well section and a well deviation well section; Utilizing the calculation information, the upper tension of the instrument segment corresponding to the current depth to be predicted is calculated; wherein the instrument segment is a segmented well section where the logging instrument is located; wherein the current depth to be predicted is any depth to be predicted; If the instrument segment is not the wellhead vertical well segment, the upper tension of the current well segment is used as the lower tension of the previous well segment, and the tension value at the wellhead tension meter corresponding to the current predicted depth is calculated based on the upper tension of the instrument segment and the calculation information; wherein the tension value is the upper tension of the wellhead vertical well segment, the current well segment is any of the well inclination segments, the previous well segment is the current well segment, and the first segmented well segment above the current well segment.

2. The method for predicting the tension of a logging cable according to claim 1, characterized in that: The step of dividing the well section to be tested into a plurality of segmented well sections comprises: According to the preset well section length, the well section of the well to be tested is divided into a plurality of segmented well sections.

3. The method for predicting the tension of a logging cable according to claim 1, characterized in that: When the current depth to be predicted is the uppermost depth of any of the segmented well sections, the calculation of the upper tension of the instrument segment corresponding to the current depth to be predicted using the calculation information includes: Using the calculation information, the well inclination of the segmented well section corresponding to the current predicted depth and the first force information corresponding to the logging instrument are obtained; wherein the first force information includes instrument buoyancy, instrument gravity, side pressure friction, mud additional friction and open leg additional friction; The upper tension of the instrument segment corresponding to the current depth to be predicted is calculated based on the well inclination of the segmented well section corresponding to the current depth to be predicted and the first force information.

4. The method for predicting the tension of a logging cable according to claim 3, characterized in that: The step of calculating the upper tension of the instrument segment corresponding to the current depth to be predicted according to the well inclination of the segmented well section corresponding to the current depth to be predicted and the first force information comprises: The upper tension of the instrument segment corresponding to the current depth to be predicted is calculated by T1=mg*cos(dev)+(mg-pgv)*sin(dev)*u+f1+f2; wherein T1 is the upper tension of the instrument segment corresponding to the current depth to be predicted, mg is the instrument gravity, dev is the well inclination of the segmented well section corresponding to the current depth to be predicted, pgv is the instrument buoyancy, (mg-pgv)*sin(dev)*u is the side pressure friction, f1 is the mud additional friction, and f2 is the open leg additional friction.

5. The method for predicting the tension of a logging cable according to claim 3, characterized in that: The method of using the upper tension of the current well section as the lower tension of the previous well section, and calculating the tension value at the wellhead tension meter corresponding to the current depth to be predicted according to the upper tension of the instrument segment and using the calculation information, comprises: Determine the segmented well section corresponding to the current depth to be predicted as the current well section; The upper tension of the current well section is used as the lower tension of the previous well section, and the upper tension of the previous well section is calculated based on the lower tension of the previous well section and the calculation information; Determine whether the previous well section is the wellhead vertical well section; If yes, the upper tension of the previous well section is determined as the tension value at the wellhead tension gauge corresponding to the current depth to be predicted; If not, the previous well section is determined as the current well section, and the step of using the upper tension of the current well section as the lower tension of the previous well section and calculating the upper tension of the previous well section based on the lower tension of the previous well section and using the calculation information is executed.

6. The method for predicting the tension of a logging cable according to claim 5, characterized in that: The step of calculating the upper tension of the previous well section by using the calculation information according to the lower tension of the previous well section comprises: Using the calculation information, obtain the well inclination of the previous well section, the solid angle corresponding to the dogleg degree and the second force information corresponding to the cable in the previous well section; wherein the second force information includes the cable buoyancy, the cable gravity, the cable side pressure friction and the cable mud additional friction; The upper tension of the previous well section is calculated based on the well inclination and the solid angle corresponding to the dogleg degree of the previous well section, the second force information and the lower tension of the previous well section.

7. The method for predicting the tension of a logging cable according to any one of claims 1 to 6, characterized in that: Also includes: A depth-tension curve is generated based on the tension values ​​at the wellhead tension meter corresponding to each of the depths to be predicted.

8. The method for predicting the tension of a logging cable according to claim 7, characterized in that: Before calculating the upper tension of the instrument segment corresponding to the current predicted depth using the calculation information, the method further includes: The maximum depth to be predicted is determined as the current depth to be predicted, and the step of using the calculation information to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted is performed; Correspondingly, after taking the upper tension of the current well section as the lower tension of the previous well section, and calculating the tension value at the wellhead tension meter corresponding to the current depth to be predicted according to the upper tension of the instrument segment and using the calculation information, the method further includes: Determine whether the current depth to be predicted is the minimum depth to be predicted; If yes, then executing the step of drawing and generating a depth-tension curve according to the tension values ​​at the wellhead tension gauges corresponding to the respective depths to be predicted; If not, the last depth to be predicted corresponding to the current depth to be predicted is determined as the current depth to be predicted, and the step of using the calculation information to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted is performed.

9. A tension prediction device for a logging cable, characterized in that: include: An information acquisition module is used to acquire calculation information of the well to be logged; wherein the calculation information includes well information of the well to be logged and model information of the logging instrument and the cable, and the well information includes well depth, well inclination, azimuth, mud viscosity and mud density; A well section division module is used to divide the well section of the well to be measured into multiple segmented well sections; wherein the segmented well sections include a wellhead vertical well section and a well deviation well section; An instrument calculation module, used to calculate the upper tension of the instrument segment corresponding to the current depth to be predicted using the calculation information; wherein the instrument segment is a segmented well section where the logging instrument is located; wherein the current depth to be predicted is any depth to be predicted; A cable calculation module is used to, if the instrument segment is not the wellhead vertical well segment, use the upper tension of the current well segment as the lower tension of the previous well segment, and calculate the tension value at the wellhead tension meter corresponding to the current predicted depth based on the upper tension of the instrument segment and the calculation information; wherein the tension value is the upper tension of the wellhead vertical well segment, the current well segment is any of the well deviated segments, and the previous well segment is the current well segment, which is the first segmented well segment above the current well segment.

10. A logging cable tension prediction device, characterized in that: include: Memory for storing computer programs; A processor is used to implement the steps of the method for predicting the tension of a logging cable as claimed in any one of claims 1 to 8 when executing the computer program.

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