Method, device and computer storage medium for obtaining horizontal well reservoir drilling rate

Abstract

The present application discloses a method, device and computer storage medium for obtaining the reservoir drilling rate of a horizontal well, and belongs to the technical field of oil and gas exploration and development. The method comprises: after obtaining the formation model of the target layer segment, determining the logging parameters on the wellbore trajectory based on the wellbore trajectory and the formation model of the horizontal well, and then determining the target length of the logging parameters of the wellbore trajectory within a specified range, that is, the reservoir drilling rate of the horizontal well can be obtained based on the ratio of the target length to the length of the wellbore trajectory. The method for obtaining the reservoir drilling rate of a horizontal well can obtain the drilling rate of the horizontal well according to the wellbore trajectory and the formation model of the horizontal well, reducing the workload of the actual measurement of the horizontal well; it solves the problem of long time consumption in obtaining the drilling rate of the horizontal well in the related technology, and achieves the effect of quickly obtaining the drilling rate of the horizontal well.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas exploration and development, and in particular to a method, a device and a computer storage medium for obtaining a horizontal well reservoir drilling rate. Background Art

[0002] A horizontal well is a special well in which, after the oil well is extended vertically or obliquely to the reservoir, the drill string continues to drill in a direction parallel to the reservoir, and a certain length of horizontal well section is maintained in the reservoir in the horizontal direction. A horizontal well includes a horizontal well section that can pass through a longer reservoir. A horizontal well has a good production capacity. However, if a thinner reservoir is encountered during the drilling of the horizontal well section, the wellbore may extend outside the reservoir, that is, the horizontal well section of the horizontal well is not in the reservoir at this point. The reservoir drilling rate of a horizontal well is the ratio of the length of the horizontal well section of the entire horizontal well to the length of the reservoir section actually drilled. The reservoir drilling rate of a horizontal well can be used to evaluate the oil and gas production of the horizontal well.

[0003] A method for obtaining the drilling rate of a horizontal well reservoir, wherein a detection tool is lowered into the horizontal well, the detection tool includes various logging instruments, and after the detection tool is lowered into the horizontal well, various parameters that change with depth can be continuously recorded along the wellbore of the horizontal well. After the staff obtains these parameters, they can identify the type and length of the underground rock formation through these parameters, and then obtain the drilling rate of the horizontal well.

[0004] In the above method, the type and length of underground rock formations are identified by using the parameters of the detection instrument, and then the horizontal well reservoir drilling rate is obtained, which is time-consuming. Summary of the invention

[0005] The embodiment of the present application provides a method, device and computer storage medium for obtaining the reservoir drilling rate of a horizontal well. The technical solution is as follows:

[0006] According to one aspect of the present application, a method for obtaining a reservoir drilling rate of a horizontal well is provided, the method comprising:

[0007] Acquiring a formation model of a target layer segment based on a well logging curve of a pilot well, wherein the pilot well and the horizontal well are located in the target layer segment, and the well logging curve is used to describe the formation lithology of the target layer segment;

[0008] Determine the logging parameters on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model;

[0009] Determine a target length of the logging parameters of the wellbore trajectory within a specified range, and when the logging parameters of any position of the wellbore trajectory are within the specified range, it is determined that the any position is located in the target reservoir;

[0010] Based on the ratio of the target length to the length of the wellbore trajectory, a reservoir encounter rate of the horizontal well is obtained.

[0011] Optionally, the obtaining of the formation model of the target layer segment based on the well logging curve of the pilot well includes:

[0012] Acquire a well logging curve of the pilot well, wherein the pilot well includes a straight pilot well or a slanted pilot well;

[0013] Square-wave the well logging curve to obtain a first well logging curve;

[0014] The target layer segment is divided into sub-layers based on the first logging curve to obtain the formation model, and the sub-layer division is used to divide the target layer segment into multiple formations according to formation lithology.

[0015] Optionally, the logging parameters include a natural gamma value, an acoustic time difference value, and a resistivity, and determining the logging parameters on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model includes:

[0016] Determine a first natural gamma value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model;

[0017] Determine a first acoustic wave time difference value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model;

[0018] A first resistivity on the wellbore trajectory is determined based on the wellbore trajectory of the horizontal well and the formation model.

[0019] Optionally, the first natural gamma value on the wellbore trajectory is determined based on the wellbore trajectory of the horizontal well and the formation model, and the first natural gamma value satisfies the formula:

[0020]

[0021] Among them, GR 总 is the first natural gamma value, GR 10 , GR 20 , GR 30 The theoretical natural gamma values ​​of three strata with different properties, FGR 10 、FGR 20 、FGR 30 are the natural gamma values ​​of three formations with different properties determined based on the wellbore trajectory of the horizontal well and the formation model, FGR 0 It is the sum of the natural gamma values ​​of all materials within the detection radius of the gamma detection instrument of three formations with different properties, determined based on the wellbore trajectory of the horizontal well and the formation model.

[0022] Optionally, the determining the first acoustic wave time difference value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model includes the following two cases:

[0023] When the acoustic wave time difference detection instrument has only one type of stratum within the detection radius, the first acoustic wave time difference value satisfies the formula:

[0024] DT=DT 0 ;

[0025] Among them, DT is the time difference of the first sound wave, DT 0 is the acoustic time difference value of the formation of this nature determined based on the wellbore trajectory of the horizontal well and the formation model;

[0026] When the detection radius of the acoustic wave time difference detection instrument includes strata of various properties, the first acoustic wave time difference value satisfies the formula:

[0027]

[0028] Among them, DT 10 and DT 20 Determine the acoustic time difference values ​​of formations of different properties on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model respectively;

[0029] S 1 and S 2 are the cross-sectional areas of strata of different properties within the detection range of the acoustic time difference detection instrument, and the cross-sectional areas are perpendicular to the wellbore trajectory of the horizontal well; S 总 It is the total cross-sectional area within the detection range of the acoustic time difference detection instrument.

[0030] Optionally, the first conductivity on the wellbore trajectory is determined based on the wellbore trajectory of the horizontal well and the formation model, and the first conductivity satisfies the formula:

[0031] σ=1 / Rt(n);

[0032] Wherein, Rt(n) is the original formation resistivity within the maximum detection range of the resistivity detection instrument determined based on the wellbore trajectory of the horizontal well and the formation model.

[0033] Optionally, determining a target length of the logging parameter of the wellbore trajectory within a specified range includes:

[0034] Acquiring logging parameters at multiple locations on the wellbore trajectory;

[0035] When the logging parameters of the multiple target positions of the wellbore trajectory are within a specified range, it is determined that the multiple target positions are located in the target reservoir;

[0036] Determine that the designated lengths on both sides of each target position of the plurality of target positions are located in the target reservoir, the plurality of positions are evenly distributed on the wellbore trajectory, and the designated length is half the distance between two adjacent positions of the plurality of positions;

[0037] The sum of the two-side designated lengths of the plurality of target positions is determined as the target length.

[0038] Optionally, obtaining a reservoir drilling rate of the horizontal well based on a ratio of the target length to the length of the wellbore trajectory includes:

[0039] The ratio of the target length to the length of the wellbore trajectory is determined as the reservoir encounter rate of the horizontal well.

[0040] According to another aspect of the present application, a device for obtaining a reservoir drilling rate of a horizontal well is provided, the device comprising:

[0041] A formation model acquisition module, used for acquiring a formation model of a target layer segment based on a well logging curve of a pilot well, wherein the pilot well and the horizontal well are located in the target layer segment, and the well logging curve is used for describing the formation lithology of the target layer segment;

[0042] A logging parameter determination module, used to determine the logging parameters on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model;

[0043] A target length determination module is used to determine the target length of the logging parameters of the wellbore trajectory within a specified range. When the logging parameters of any position of the wellbore trajectory are within the specified range, it is determined that the any position is located in the target reservoir;

[0044] The reservoir drilling rate acquisition module is used to acquire the reservoir drilling rate of the horizontal well based on the ratio of the target length to the length of the wellbore trajectory.

[0045] According to another aspect of the present application, a computer storage medium is provided, in which at least one instruction, at least one program, a code set or an instruction set is stored, and the at least one instruction, the at least one program, the code set or the instruction set is loaded and executed by a processor to implement the method for obtaining the reservoir drilling rate of a horizontal well as described above.

[0046] The beneficial effects brought by the technical solution provided by the embodiment of the present application include at least:

[0047] A method for obtaining a reservoir drilling rate of a horizontal well is provided. After obtaining a formation model of a target layer section, the logging parameters on the wellbore trajectory are determined based on the wellbore trajectory and the formation model of the horizontal well, and then the target length of the logging parameters of the wellbore trajectory within a specified range is determined, that is, the reservoir drilling rate of the horizontal well can be obtained based on the ratio of the target length to the length of the wellbore trajectory. The method for obtaining a reservoir drilling rate of a horizontal well can obtain the drilling rate of the horizontal well according to the wellbore trajectory and the formation model of the horizontal well, reducing the workload of actual measurement of the horizontal well; solving the problem of a long time consumption in obtaining the drilling rate of the horizontal well in related technologies, and achieving the effect of quickly obtaining the drilling rate of the horizontal well. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0049] Figure 1 is a flow chart of a method for obtaining a horizontal well reservoir drilling rate shown in an embodiment of the present application;

[0050] Figure 2 is a flow chart of another method for obtaining a horizontal well reservoir drilling rate shown in an embodiment of the present application;

[0051] Figure 3 is a schematic diagram of a well logging curve of a pilot well provided in an embodiment of the present application;

[0052] Figure 4 is a schematic diagram of a first well logging curve provided in an embodiment of the present application;

[0053] Figure 5 It is a schematic diagram of a sub-layer division and formation model provided in an embodiment of the present application;

[0054] Figure 6 is a schematic diagram of a natural gamma ray detection schematic diagram shown in an embodiment of the present application;

[0055] Figure 7 This is a schematic diagram of the principle of acoustic logging provided by an embodiment of the present application;

[0056] Figure 8 This is a detection schematic diagram of an acoustic wave time difference detection instrument shown in an embodiment of the present application;

[0057] Fig. 9 It is a detection schematic diagram of another acoustic wave time difference detection instrument shown in an embodiment of the present application;

[0058] Fig.10 yes Figure 2 A flowchart of the method for determining that any position is located in a target reservoir;

[0059] Fig.11 It is a structural block diagram of a device for obtaining a reservoir drilling rate of a horizontal well provided in an embodiment of the present application.

[0060] The above drawings have shown clear embodiments of the present application, which will be described in more detail later. These drawings and text descriptions are not intended to limit the scope of the present application in any way, but to illustrate the concept of the present application to those skilled in the art by referring to specific embodiments. DETAILED DESCRIPTION

[0061] In order to make the objectives, technical solutions and advantages of the present application clearer, the implementation methods of the present application will be further described in detail below with reference to the accompanying drawings.

[0062] Figure 1 : is a flow chart of a method for obtaining a horizontal well reservoir drilling rate shown in an embodiment of the present application. The method may include the following steps:

[0063] Step 101: Acquire a formation model of a target layer segment based on a well logging curve of a pilot well. The pilot well and the horizontal well are located in the target layer segment. The well logging curve is used to describe the formation lithology of the target layer segment.

[0064] Step 102: determine the logging parameters on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model.

[0065] Step 103, determining a target length of the logging parameters of the wellbore trajectory within a specified range. When the logging parameters of any position of the wellbore trajectory are within the specified range, it is determined that any position is located in the target reservoir.

[0066] Step 104: Obtain the reservoir encounter rate of the horizontal well based on the ratio of the target length to the length of the wellbore trajectory.

[0067] In summary, the method for obtaining the reservoir drilling rate of a horizontal well provided in an embodiment of the present application, after obtaining the formation model of the target layer segment, determines the logging parameters on the wellbore trajectory based on the wellbore trajectory and the formation model of the horizontal well, and then determines the target length of the logging parameters of the wellbore trajectory within a specified range. When the logging parameters at any position of the wellbore trajectory are within the specified range, it is determined that any position is located in the target reservoir, that is, the reservoir drilling rate of the horizontal well can be obtained based on the ratio of the target length to the length of the wellbore trajectory. The method for obtaining the reservoir drilling rate of a horizontal well can obtain the drilling rate of the horizontal well according to the wellbore trajectory and the formation model of the horizontal well, thereby reducing the workload of actual measurement of the horizontal well; it solves the problem of a long time spent in obtaining the drilling rate of a horizontal well in the related art, and achieves the effect of quickly obtaining the drilling rate of the horizontal well.

[0068] Figure 2 FIG. 1 is a flow chart of another method for obtaining a horizontal well reservoir drilling rate shown in an embodiment of the present application. The method may include the following steps:

[0069] Step 201, obtaining a well logging curve of a pilot well, wherein the pilot well includes a straight pilot well or an inclined pilot well, the pilot well and the horizontal well are located in a target layer section, and the well logging curve refers to a curve formed during well logging, which is used to describe the lithology and position of the target layer section.

[0070] A pilot well is a well drilled to obtain geological data, determine the position of the formation, and lay the foundation for the construction of the horizontal section of the horizontal well when the geological conditions of the well location are not clear. Its purpose is to understand the lithology, physical properties, electrical properties, oil content, oil-water relationship, structural conditions and changes of the target layer. The pilot well can be a straight pilot well or an inclined pilot well. The straight pilot well is far away from the starting point of the horizontal section of the horizontal well. When the geological conditions are relatively complex, the straight pilot well cannot meet the measurement requirements, so an inclined pilot well needs to be drilled. The target layer section is the formation section where the horizontal well is located.

[0071] like Figure 3 As shown, Figure 3 It is a schematic diagram of a logging curve of a pilot well provided in an embodiment of the present application. The logging curve can reflect the stratigraphic lithology of the target layer segment. The extension direction y of the logging curve is parallel to the vertical direction, and the vertical direction can be the gravity direction. The bending direction x1 of the logging curve can include the value of the logging curve, which can reflect different lithologies and stratigraphic characteristics.

[0072] Step 202: convert the well logging curve into a square wave to obtain a first well logging curve.

[0073] The obtained well logging curve of the pilot well is squared so as to facilitate stratigraphic division of the target layer section according to the squared first well logging curve.

[0074] like Figure 4 As shown, Figure 4 It is a schematic diagram of a first logging curve provided in an embodiment of the present application. The extension direction y of the first logging curve is parallel to the vertical direction, and the vertical direction may be the gravity direction. The bending direction x1 of the first logging curve may include the value of the logging curve, which may reflect the characteristics of different lithologies and stratigraphic positions. The first logging curve may more clearly show the differences between strata of various properties.

[0075] Step 203: divide the target layer into sub-layers based on the first logging curve to obtain a formation model, wherein the sub-layer division is used to divide the target layer into multiple formations according to the formation lithology.

[0076] Sub-layer division is the basis of reservoir geological characteristic research and the premise of describing reservoir morphology and spatial distribution characteristics of its parameters. Sub-layer division of the target layer based on the first logging curve can obtain the spatial variation law of each stratum.

[0077] like Figure 5 As shown, Figure 5 It is a schematic diagram of a sub-layer division and a formation model provided in an embodiment of the present application. According to the result of the sub-layer division, a corresponding formation model can be established. The formation model is a formation model of the formation section where the horizontal well is located. It can include a variety of formations with different properties in the formation section where the horizontal well is located, and can be used to represent the formation conditions of the formation section where the horizontal well is located. The direction y of the formation model superposition is parallel to the vertical direction, and the vertical direction can be the gravity direction. The direction x2 of the formation model extension can be parallel to the horizontal direction, and the horizontal direction is perpendicular to the gravity direction.

[0078] After combining the wellbore trajectory of the horizontal well with the formation model, the formation conditions at each position on the wellbore trajectory of the horizontal well can be obtained based on the wellbore trajectory of the horizontal well and the formation model, and then the logging data at each position on the wellbore trajectory of the horizontal well can be obtained.

[0079] Step 204: Determine a first natural gamma value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model.

[0080] After the wellbore trajectory and the formation model of the horizontal well are obtained, the wellbore trajectory of the horizontal well can be combined with the formation model to calculate the well logging response of the horizontal well in the formation model.

[0081] The logging method used to determine the first natural gamma value on the borehole trajectory is natural gamma logging, which refers to the method of measuring the natural gamma ray intensity of the rock formation along the trajectory of the horizontal well. Rocks generally contain different amounts of radioactive elements and continuously emit radiation. For example, in igneous rocks, the more acidic, the greater the radioactivity; in sedimentary rocks, the more muddy, the stronger the radioactivity. Using these rules, it is possible to divide the geological profile of the borehole, determine the sandstone mud content in the sandstone mudstone profile, and qualitatively judge the permeability of the rock formation based on the results of natural gamma logging. It can then be determined whether the formation is a reservoir.

[0082] The first natural gamma value satisfies the formula:

[0083]

[0084] Among them, GR 总 is the first natural gamma value, GR 10 , GR 20 , GR 30 The theoretical natural gamma values ​​of three strata with different properties, FGR 10 、FGR 20 、FGR 30 The natural gamma values ​​of three formations with different properties are determined based on the horizontal well trajectory and formation model, FGR 0 It is the sum of the natural gamma values ​​of all materials within the detection radius of the natural gamma detection instrument for three formations with different properties, determined based on the wellbore trajectory and formation model of the horizontal well.

[0085] Among them, FGR 0 、FGR 10 、FGR 20 and FGR 30 Satisfies the following formula:

[0086]

[0087] Where r is the natural gamma detection radius, μ 地层 is the formation gamma-ray absorption coefficient, r 地层 is the distance that the gamma ray emitted by the natural gamma ray detection instrument travels in the calculated stratum (the calculated stratum may include one stratum with different properties or three stratums with different properties), μ 泥浆 is the mud gamma-ray absorption coefficient, r 泥浆 is the distance that the gamma rays emitted by the natural gamma ray detection instrument travel in the mud, Ω 球 is the maximum detection radius of the natural gamma instrument, Ω 井 is the wellbore radius, and n is 0, 10, 20 and 30.

[0088] It should be noted that strata of different nature refer to different physical properties of the strata themselves. For example, due to the different physical properties of igneous rocks, sedimentary rocks and metamorphic rocks in the strata, the natural gamma values ​​obtained from strata of different nature within the same gamma-ray detection range are different, and the theoretical natural gamma value is a fixed value.

[0089] Also, 0, 10, 20, and 30 are used only to number different stratigraphic layers and are not to be understood as indicating or implying relative importance.

[0090] like Figure 6 As shown, Figure 6 It is a schematic diagram of a natural gamma detection schematic diagram shown in an embodiment of the present application. Since the natural gamma detection radius is relatively small, about 0.4m-0.5m, illustratively, the detection range of the natural gamma detection instrument involves the interface B1 and B2 of two strata. When the detection range involves two interface B1 and B2, the detection range includes three strata of different properties, namely, the first stratum 601, the second stratum 602 and the third stratum 603. According to the proportion of the three strata in the detection range of the horizontal well, there are correspondingly 6 types of interface formation models. The formula of the first natural gamma value in the embodiment of the present application is applicable to the above 6 types of interface formation models.

[0091] Step 205: Determine the first acoustic wave time difference value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model.

[0092] The logging method used to determine the first acoustic time difference value on the wellbore trajectory is acoustic logging. Acoustic logging refers to a logging method that uses the acoustic characteristics of different rocks, such as the speed, amplitude and frequency changes, to study the geological profile of horizontal wells. The machine used in acoustic logging is an acoustic transmitter. Acoustic time difference logging can be used to determine the porosity of rock formations, identify lithology, compare formations, and judge gas formations. The denser the rock, the smaller the time difference, and the looser the rock, the greater the porosity and the greater the time difference. Since the speed of sound waves in water is greater than that in oil, and the speed of sound waves in oil is greater than that in natural gas, when the rock pores contain different fluids, it can be reflected in the value of the acoustic time difference.

[0093] like Figure 7 As shown, Figure 7It is a schematic diagram of the principle of an acoustic logging provided in an embodiment of the present application. The sonic logging instrument may include an acoustic wave transmitter and two receivers. The acoustic wave generator sound 701 transmits acoustic waves to the well wall, generates sliding waves on the well wall, and is received by the first receiver 702 and the second receiver 703. The difference in the arrival time of the acoustic waves received by the first receiver 702 and the second receiver 703 is only affected by the formations near the first receiver 702 and the second receiver 703. The acoustic wave time difference of different rock formations on the horizontal wellbore trajectory can be obtained through the two receivers, and then the properties of the formation can be judged to determine whether the formation is a reservoir.

[0094] like Figure 8 As shown, Figure 8 1 is a schematic diagram of a detection of an acoustic wave time difference detection instrument shown in an embodiment of the present application. When there is a stratum 801 of a certain property within the detection radius of the acoustic wave time difference detection instrument, the first acoustic wave time difference value satisfies the formula:

[0095] DT=DT 0 ;

[0096] Among them, DT is the time difference of the first sound wave, DT 0 The acoustic time difference value of the formation of this nature determined based on the wellbore trajectory of the horizontal well and the formation model;

[0097] like Fig. 9 As shown, Fig. 9 901 and 902, respectively. FIG. 902 is a schematic diagram of another acoustic wave time difference detection instrument detection method shown in an embodiment of the present application. When the acoustic wave time difference detection instrument detection radius includes two types of strata (the fourth stratum 901 and the fifth stratum 902), the first acoustic wave time difference value satisfies the formula:

[0098]

[0099] Among them, DT 10 and DT 20 The acoustic time difference values ​​of formations with different properties on the wellbore trajectory are determined based on the wellbore trajectory of the horizontal well and the formation model.

[0100] S 1 and S 2 are the cross-sectional areas of strata of different properties within the detection range of the acoustic time difference detection instrument, and the cross-sectional areas are perpendicular to the wellbore trajectory of the horizontal well; S 总 It is the total cross-sectional area within the detection range of the acoustic time difference detection instrument.

[0101] It should be noted that when the detection radius of the acoustic wave time difference detection instrument includes strata of two properties, there are three corresponding layer interface strata models according to the proportion of the two strata in the detection range of the acoustic wave detector. When the detection radius of the acoustic wave time difference detection instrument includes strata of three or more properties, the calculation idea is the same as that of strata of two properties, and the embodiments of the present application will not be repeated here.

[0102] Step 206: Determine a first conductivity on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model.

[0103] The logging method used to determine the first conductivity on the wellbore trajectory is resistivity logging, which is a method of measuring the resistivity of rock (including the fluid therein) by using power supply electrodes and measuring electrodes arranged at different positions in the wellbore of a horizontal well.

[0104] The first conductivity satisfies the formula:

[0105] σ=1 / Rt(n);

[0106] Wherein, Rt(n) is the original formation resistivity within the maximum detection range of the resistivity detection instrument, which is determined based on the wellbore trajectory and formation model of the horizontal well.

[0107] Step 207, determining the target length of the logging parameters of the wellbore trajectory within the specified range. When the logging parameters of any position of the wellbore trajectory are within the specified range, it is determined that any position is located in the target reservoir.

[0108] If the logging parameters of the wellbore trajectory are within the specified range, it can be shown that the formation on the wellbore trajectory is a reservoir.

[0109] like Fig.10 As shown, step 207 may include the following four sub-steps:

[0110] Sub-step 2071, obtaining logging parameters at multiple locations on the wellbore trajectory.

[0111] For example, the length of the horizontal well is 850 meters. On the wellbore trajectory of the horizontal well, 8 measurement points are taken every 1 meter, that is, the logging parameters of 6800 positions on the wellbore trajectory of the horizontal well are obtained.

[0112] Sub-step 2072: When the logging parameters of the multiple target positions of the wellbore trajectory are within the specified range, it is determined that the multiple target positions are located in the target reservoir.

[0113] When the logging parameters of the target position are within the specified range, it means that the first natural gamma value, the first acoustic wave time difference value and the first conductivity of the target position are within the specified range.

[0114] Exemplarily, when the first natural gamma value of the target location is less than 50gAPI, the first acoustic time difference value is greater than 50us / ft, and the first conductivity range is within 0.001 to 0.01S / m, it is confirmed that the logging parameters of the target location are within the specified range, and it can be determined that the target location is located in the target reservoir.

[0115] Sub-step 2073, determining that the designated lengths on both sides of each target position among the multiple target positions are located in the target reservoir, the multiple positions are evenly distributed on the wellbore trajectory, and the designated length is half the distance between two adjacent positions among the multiple positions.

[0116] When two adjacent target positions are both located in the target reservoir, it can be considered that the distance between the two target positions is also located in the target reservoir. When the target positions on both sides of a target position are not located in the target reservoir, it can be considered that the specified length on both sides of the target position is located in the target reservoir.

[0117] Sub-step 2074: determine the sum of the specified lengths on both sides of the multiple target positions as the target length.

[0118] The sum of the designated lengths on both sides of the multiple target positions may be the sum of the lengths of the target reservoirs, that is, the target length may be used to represent the length of the target reservoir on the horizontal wellbore trajectory.

[0119] Step 208: Obtain the reservoir encounter rate of the horizontal well based on the ratio of the target length to the length of the wellbore trajectory.

[0120] The ratio of the target length to the length of the wellbore trajectory is determined as the reservoir drilling rate of the horizontal well. The drilling rate of the horizontal balance is obtained to estimate the production of the horizontal well and provide data support for subsequent production plans.

[0121] Exemplarily, using the method for obtaining the reservoir drilling rate of a horizontal well, it is calculated that the drilling rate of the G003-H17 well in the Southwest Oil and Gas Field is 80%.

[0122] To summarize, the method for obtaining the reservoir drilling rate of a horizontal well provided in an embodiment of the present application, after obtaining the formation model of the target layer segment, determines the logging parameters on the wellbore trajectory based on the wellbore trajectory and the formation model of the horizontal well, and then determines the target length of the logging parameters of the wellbore trajectory within a specified range, that is, the reservoir drilling rate of the horizontal well can be obtained based on the ratio of the target length to the length of the wellbore trajectory. The method for obtaining the reservoir drilling rate of a horizontal well can obtain the drilling rate of the horizontal well according to the wellbore trajectory and the formation model of the horizontal well, thereby reducing the workload of actual measurement of the horizontal well; it solves the problem of a long time spent in obtaining the drilling rate of a horizontal well in the related art, and achieves the effect of quickly obtaining the drilling rate of the horizontal well.

[0123] Fig.11 1 is a structural block diagram of a device for obtaining a reservoir drilling rate of a horizontal well provided in an embodiment of the present application. The device 1100 for obtaining a reservoir drilling rate of a horizontal well includes:

[0124] The formation model acquisition module 1110 is used to acquire the formation model of the target layer segment based on the well logging curve of the pilot well. The pilot well and the horizontal well are located in the target layer segment, and the well logging curve is used to describe the formation lithology of the target layer segment.

[0125] The logging parameter determination module 1120 is used to determine the logging parameters on the wellbore trajectory based on the wellbore trajectory and the formation model of the horizontal well.

[0126] The target length determination module 1130 is used to determine the target length of the logging parameters of the wellbore trajectory within a specified range. When the logging parameters of any position of the wellbore trajectory are within the specified range, it is determined that any position is located in the target reservoir.

[0127] The reservoir drilling rate acquisition module 1140 is used to acquire the reservoir drilling rate of the horizontal well based on the ratio of the target length to the length of the wellbore trajectory.

[0128] In summary, the device for obtaining the reservoir drilling rate of a horizontal well and the method for obtaining the reservoir drilling rate of a horizontal well provided in the embodiments of the present application, after obtaining the formation model of the target layer segment, determine the logging parameters on the wellbore trajectory based on the wellbore trajectory and the formation model of the horizontal well, and then determine the target length of the logging parameters of the wellbore trajectory within a specified range, that is, the reservoir drilling rate of the horizontal well can be obtained based on the ratio of the target length to the length of the wellbore trajectory. The method for obtaining the reservoir drilling rate of a horizontal well can obtain the drilling rate of the horizontal well according to the wellbore trajectory and the formation model of the horizontal well, thereby reducing the workload of actual measurement of the horizontal well; it solves the problem of long time consumption in obtaining the drilling rate of the horizontal well in the related technology, and achieves the effect of quickly obtaining the drilling rate of the horizontal well.

[0129] In addition, an embodiment of the present application also provides a computer storage medium, which stores at least one instruction, at least one program, code set or instruction set, and the at least one instruction, at least one program, code set or instruction set is loaded and executed by a processor to implement any of the methods for obtaining the reservoir drilling rate of a horizontal well provided in the above embodiments.

[0130] In the present application, the terms "first", "second", "third", "fourth" and "fifth" are used for descriptive purposes only and should not be understood as indicating or implying relative importance. The term "plurality" refers to two or more, unless otherwise clearly defined.

[0131] The above description is only an optional embodiment of the present application and is not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application shall be included in the protection scope of the present application.

Claims

1. A method for obtaining a reservoir drilling rate of a horizontal well, characterized in that: The method comprises: Acquiring a formation model of a target layer segment based on a well logging curve of a pilot well, wherein the pilot well and the horizontal well are located in the target layer segment, and the well logging curve is used to describe the formation lithology of the target layer segment; Determine the logging parameters on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model; Determine a target length of the logging parameters of the wellbore trajectory within a specified range, and when the logging parameters of any position of the wellbore trajectory are within the specified range, it is determined that the any position is located in the target reservoir; Obtaining a reservoir drilling rate of the horizontal well based on a ratio of the target length to the length of the wellbore trajectory; Wherein, determining the target length of the logging parameter of the wellbore trajectory within a specified range includes: Acquiring logging parameters at multiple locations on the wellbore trajectory; When the logging parameters of the multiple target positions of the wellbore trajectory are within a specified range, it is determined that the multiple target positions are located in the target reservoir; Determine that the designated lengths on both sides of each target position of the plurality of target positions are located in the target reservoir, the plurality of positions are evenly distributed on the wellbore trajectory, and the designated length is half the distance between two adjacent positions of the plurality of positions; The sum of the two-side designated lengths of the plurality of target positions is determined as the target length.

2. The method according to claim 1, characterized in that: The method of obtaining the formation model of the target layer segment based on the well logging curve of the pilot well includes: Acquire a well logging curve of the pilot well, wherein the pilot well includes a straight pilot well or a slanted pilot well; Square-wave the well logging curve to obtain a first well logging curve; The target layer segment is divided into sub-layers based on the first logging curve to obtain the formation model, and the sub-layer division is used to divide the target layer segment into multiple formations according to formation lithology.

3. The method according to claim 1, characterized in that The logging parameters include natural gamma value, acoustic time difference value and resistivity, and the logging parameters on the wellbore trajectory are determined based on the wellbore trajectory of the horizontal well and the formation model, including: Determine a first natural gamma value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model; Determine a first acoustic wave time difference value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model; A first resistivity on the wellbore trajectory is determined based on the wellbore trajectory of the horizontal well and the formation model.

4. The method according to claim 3, characterized in that The first natural gamma value on the wellbore trajectory is determined based on the wellbore trajectory of the horizontal well and the formation model, and the first natural gamma value satisfies the formula: Among them, GR 总 is the first natural gamma value, GR 10 , GR 20 , GR 30 The theoretical natural gamma values ​​of three strata with different properties, FGR 10 、FGR 20 、FGR 30 are the natural gamma values ​​of three formations of different properties determined based on the wellbore trajectory of the horizontal well and the formation model, and FGR0 is the sum of the natural gamma values ​​of all substances within the detection radius of the gamma detection instrument for three formations of different properties determined based on the wellbore trajectory of the horizontal well and the formation model.

5. The method according to claim 3, characterized in that: The determining of the first acoustic wave time difference value on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model includes the following two cases: When the acoustic wave time difference detection instrument has only one type of stratum within the detection radius, the first acoustic wave time difference value satisfies the formula: DT = DT0; Wherein, DT is the first acoustic time difference value, and DT0 is the acoustic time difference value of the formation of this nature determined based on the wellbore trajectory of the horizontal well and the formation model; When the detection radius of the acoustic wave time difference detection instrument includes strata of various properties, the first acoustic wave time difference value satisfies the formula: Among them, DT 10 and DT 20 Determine the acoustic time difference values ​​of formations of different properties on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model respectively; S1 and S2 are the cross-sectional areas of strata of different properties within the detection range of the acoustic time difference detection instrument, respectively, and the cross-sectional areas are perpendicular to the borehole trajectory of the horizontal well; S 总 It is the total cross-sectional area within the detection range of the acoustic time difference detection instrument.

6. The method according to claim 3, characterized in that: The first conductivity on the wellbore trajectory is determined based on the wellbore trajectory of the horizontal well and the formation model, and the first conductivity satisfies the formula: σ=1 / Rt(n); Wherein, Rt(n) is the original formation resistivity within the maximum detection range of the resistivity detection instrument determined based on the wellbore trajectory of the horizontal well and the formation model.

7. The method according to claim 1, characterized in that Obtaining a reservoir drilling rate of the horizontal well based on a ratio of the target length to the length of the wellbore trajectory includes: The ratio of the target length to the length of the wellbore trajectory is determined as the reservoir encounter rate of the horizontal well.

8. A device for obtaining a reservoir drilling rate of a horizontal well, characterized in that: The device for obtaining the reservoir drilling rate of the horizontal well comprises: A formation model acquisition module, used for acquiring a formation model of a target layer segment based on a well logging curve of a pilot well, wherein the pilot well and the horizontal well are located in the target layer segment, and the well logging curve is used for describing the formation lithology of the target layer segment; A logging parameter determination module, used to determine the logging parameters on the wellbore trajectory based on the wellbore trajectory of the horizontal well and the formation model; A target length determination module is used to determine the target length of the logging parameters of the wellbore trajectory within a specified range. When the logging parameters of any position of the wellbore trajectory are within the specified range, it is determined that the any position is located in the target reservoir; A reservoir drilling rate acquisition module, used to acquire the reservoir drilling rate of the horizontal well based on the ratio of the target length to the length of the wellbore trajectory; Wherein, the target length determination module is used to: Acquiring logging parameters at multiple locations on the wellbore trajectory; When the logging parameters of the multiple target positions of the wellbore trajectory are within a specified range, it is determined that the multiple target positions are located in the target reservoir; Determine that the designated lengths on both sides of each target position of the plurality of target positions are located in the target reservoir, the plurality of positions are evenly distributed on the wellbore trajectory, and the designated length is half the distance between two adjacent positions of the plurality of positions; The sum of the two-side designated lengths of the plurality of target positions is determined as the target length.

9. A computer storage medium, characterized in that: The computer storage medium stores at least one instruction, at least one program, a code set or an instruction set, and the at least one instruction, the at least one program, the code set or the instruction set are loaded and executed by the processor to implement the method for obtaining the reservoir drilling rate of a horizontal well as described in any one of claims 1 to 7.

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