Method, device, equipment and storage medium for detecting annulus flow pressure drop of wellbore

Abstract

This invention discloses a method, apparatus, equipment, and storage medium for detecting annular flow pressure drop in wellbore. The method includes: fitting acquired electrical logging data of the well diameter of the target well; processing an irregularly enlarged well section into a concave arc-shaped wellbore to be tested; obtaining the maximum diameter and concave height of the concave arc-shaped wellbore; determining the diameter enlargement factor of the concave arc-shaped wellbore based on the maximum diameter and the pre-acquired drill bit diameter of the target well; and inputting the diameter enlargement factor, the concave height, and the drilling data of the target well into a pre-constructed model of an irregular wellbore annular flow pressure drop in a reference well for calculation to obtain the annular flow pressure drop of the target well. This method enables rapid detection of the annular flow pressure drop of the target well based on the annular flow pressure drop of the reference well, improving the detection efficiency of annular flow pressure drop in irregular wellbore annulus.

Description

Technical Field

[0001] This invention belongs to the field of cementing technology in oil drilling and production engineering, and specifically relates to a method, device, equipment and storage medium for detecting the flow pressure drop in the wellbore annulus. Background Technology

[0002] In recent years, with the increasing scale of oil and gas exploration and development, narrow-density window formations are becoming more and more common, making accurate calculation of annular flow pressure drop increasingly important.

[0003] Due to the heterogeneity of the formation, formations at different depths often exhibit varying degrees of borehole enlargement, easily forming irregular wellbores such as "bulging bellies" or "skewered" shapes. These irregular wellbores inevitably affect the annular pressure drop. However, current calculations of annular pressure drop assume a regular, smooth wellbore, neglecting the impact of such irregularities. This results in inaccurate annular pressure calculations, directly impacting drilling safety.

[0004] This problem can be solved using numerical simulation techniques for fluid flow based on computational fluid dynamics (CFD), but a well may have multiple irregular well sections, and numerical simulation takes too long.

[0005] Therefore, how to improve the detection efficiency of annular flow pressure drop in irregular wellbore is a technical problem that urgently needs to be solved by those skilled in the art. Summary of the Invention

[0006] The main objective of this invention is to provide a method, apparatus, equipment, and storage medium for detecting annular flow pressure drop in wellbore, in order to solve the technical problem of low efficiency in detecting annular flow pressure drop in irregular wellbore in the prior art.

[0007] To address the above problems, this invention provides a method for detecting the annular flow pressure drop in wellbore, comprising:

[0008] Obtain a series of electrical logging diameter data for the well to be logged;

[0009] The series of electrical logging data of the well to be tested are fitted, the irregular enlarged well section is processed into the arc-shaped concave wellbore to be tested, and the maximum well diameter and the concave height of the arc-shaped concave wellbore to be tested are obtained.

[0010] The well diameter enlargement factor of the arc-shaped concave wellbore to be tested is determined based on the maximum well diameter of the wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance.

[0011] The wellbore enlargement factor of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested are input into the pre-constructed irregular wellbore annular flow pressure drop model of the reference well for calculation to obtain the irregular wellbore annular flow pressure drop of the well to be tested; wherein, the drill bit diameter of the well to be tested is matched with the drill bit diameter of the reference well.

[0012] Furthermore, in the above-described method for detecting wellbore annular flow pressure drop, the process of constructing the model for calculating the irregular wellbore annular flow pressure drop of the reference well includes:

[0013] Obtain a series of electrical logging caliper data for the reference well;

[0014] The electrical logging data of the reference well are fitted to form an irregular enlarged well section into a reference arc-shaped concave wellbore, and the maximum well diameter and concave height of the reference arc-shaped concave wellbore are obtained.

[0015] The well diameter enlargement factor of the reference arc-shaped concave wellbore is determined based on the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the reference well obtained in advance.

[0016] Based on the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the preset coefficient adjustment step size, a sample wellbore enlargement coefficient is generated at the concave height of the reference arc-shaped concave wellbore; wherein, the sample wellbore enlargement coefficient includes the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the adjusted wellbore enlargement coefficient.

[0017] Based on the pre-acquired drilling data of the reference well and the preset drilling data adjustment step size, sample drilling data at the concave height of the reference arc-shaped concave wellbore is generated; wherein, the sample drilling data includes the drilling data of the reference well and the adjusted drilling data;

[0018] The concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient are input into a preset fluid flow numerical simulation model for calculation, to obtain the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore.

[0019] Based on the irregular wellbore annular flow pressure drop of the reference well, an annular flow pressure drop model of the reference well is constructed.

[0020] Furthermore, in the above-described method for detecting the annular flow pressure drop in the wellbore, the drilling data of the reference well includes at least one of the following: the outer diameter of the casing of the reference well, the drilling fluid density of the reference well, the plastic viscosity of the drilling fluid of the reference well, the dynamic shear force of the drilling fluid of the reference well, and the circulating displacement of the drilling fluid of the reference well.

[0021] The drilling data of the well to be logged includes at least one of the following: casing outer diameter value Dc, drilling fluid density value, drilling fluid plastic viscosity value, drilling fluid dynamic shear force value, and drilling fluid circulation displacement value; and the data type of the drilling data of the well to be logged is consistent with the data type of the drilling data of the reference well.

[0022] Furthermore, in the above-described method for detecting the annular flow pressure drop in wellbore, the wellbore diameter enlargement factor of the arc-shaped concave wellbore to be tested is determined based on the maximum wellbore diameter of the wellbore to be tested and the pre-acquired drill bit diameter of the well to be tested, including:

[0023] The maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested are substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested.

[0024] The formula for calculating the magnification factor of the well to be logged is:

[0025] ηi′=(Dai′-Db′) / Db′;

[0026] Wherein, ηi′ represents the well diameter enlargement coefficient of the i-th arc-shaped concave wellbore to be tested, Dai′ represents the maximum well diameter of the arc-shaped concave wellbore to be tested, and Db′ represents the drill bit diameter of the well to be tested.

[0027] Furthermore, in the above-described method for detecting the annular flow pressure drop in wellbore, fitting the series of electrical logging data of the well to be tested, and processing the irregular enlarged well section into the arc-shaped concave wellbore to be tested, includes:

[0028] Based on the least squares method, the series of electrical logging diameter data of the well to be measured are fitted, and the irregular enlarged diameter section is processed into the arc-shaped concave wellbore to be measured.

[0029] The present invention also provides a device for detecting the pressure drop in the annulus flow of a wellbore, comprising:

[0030] The acquisition module is used to acquire a series of electrical logging diameter data for the well to be logged;

[0031] The fitting module is used to fit the series of electrical logging diameter data of the well to be tested, process the irregular enlarged diameter section into the arc-shaped concave wellbore to be tested, and obtain the maximum diameter of the arc-shaped concave wellbore to be tested and the concave height of the arc-shaped concave wellbore to be tested.

[0032] The first determining module is used to determine the well diameter enlargement factor of the arc-shaped concave wellbore to be tested based on the maximum well diameter of the wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance.

[0033] The second determining module is used to input the well diameter enlargement factor of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested into a pre-constructed irregular wellbore annular flow pressure drop model of a reference well to calculate the irregular wellbore annular flow pressure drop of the well to be tested; wherein, the drill bit diameter of the well to be tested is matched with the drill bit diameter of the reference well.

[0034] Furthermore, the aforementioned wellbore annular flow pressure drop detection device also includes a first adjustment module, a second adjustment module, and a construction module;

[0035] The acquisition module is also used to acquire electrical logging caliper series data of the reference well;

[0036] The fitting module is also used to fit the electrical logging diameter series data of the reference well, process the irregular enlarged well section into a reference arc-shaped concave wellbore, and obtain the maximum well diameter and concave height of the reference arc-shaped concave wellbore.

[0037] The first determining module is further configured to determine the well diameter enlargement factor of the reference arc-shaped concave wellbore based on the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the reference well obtained in advance;

[0038] The first adjustment module is further configured to generate a sample well diameter expansion coefficient at the concave height of the reference arc-shaped concave wellbore based on the well diameter expansion coefficient of the reference arc-shaped concave wellbore and a preset coefficient adjustment step size; wherein, the sample well diameter expansion coefficient includes the well diameter expansion coefficient of the reference arc-shaped concave wellbore and the adjusted well diameter expansion coefficient.

[0039] The second adjustment module is further configured to adjust the step size based on the pre-acquired drilling data of the reference well and the preset drilling data, and generate sample drilling data at the concave height of the reference arc-shaped concave wellbore; wherein, the sample drilling data includes the drilling data of the reference well and the adjusted drilling data;

[0040] The second determining module inputs the concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient into a preset fluid flow numerical simulation model for calculation, and obtains the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore.

[0041] The construction module is also used to construct an irregular wellbore annular flow pressure drop model of the reference well based on the irregular wellbore annular flow pressure drop of the reference well.

[0042] Furthermore, in the aforementioned wellbore annular flow pressure drop detection device, the first determining module is also used for:

[0043] The maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested are substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested.

[0044] The formula for calculating the magnification factor of the well to be logged is:

[0045] ηi′=(Dai′-Db′) / Db′;

[0046] Wherein, ηi′ represents the well diameter enlargement coefficient of the i-th arc-shaped concave wellbore to be tested, Dai′ represents the maximum well diameter of the arc-shaped concave wellbore to be tested, and Db′ represents the drill bit diameter of the well to be tested.

[0047] The present invention also provides a device for detecting the pressure drop of wellbore annulus flow, including a memory and a processor;

[0048] The memory stores a computer program, which, when executed by a processor, implements the steps of the wellbore annular flow pressure drop detection method as described in any of the preceding claims.

[0049] The present invention also provides a storage medium having a computer program stored thereon, which, when executed by a processor, implements the steps of the wellbore annular flow pressure drop detection method as described in any of the preceding claims.

[0050] The present invention also provides a storage medium storing a computer program thereon, which, when executed by a processor, implements the steps of the method for detecting the distribution information of organic-rich shale clay described in any of the preceding claims.

[0051] Compared with the prior art, one or more embodiments of the above solutions may have the following advantages or beneficial effects:

[0052] The present invention discloses a method, apparatus, equipment, and storage medium for detecting annular flow pressure drop in wellbore. By fitting a series of electrical logging data of the well to be tested, irregular enlarged well sections are processed into arc-shaped concave wellbore sections to be tested. The maximum diameter and concave height of the arc-shaped concave wellbore to be tested are obtained. Based on the maximum diameter of the arc-shaped concave wellbore to be tested and the pre-acquired drill bit diameter of the well to be tested, a diameter enlargement factor for the arc-shaped concave wellbore to be tested is determined. Then, the diameter enlargement factor, the concave height, and the drilling data of the well to be tested are input into a pre-constructed model of an irregular wellbore annular flow pressure drop in a reference well for calculation, thereby obtaining the annular flow pressure drop of the irregular wellbore to be tested. This achieves rapid detection of the annular flow pressure drop of the irregular wellbore to be tested based on the annular flow pressure drop of the reference well, improving the detection efficiency of annular flow pressure drop in irregular wellbore.

[0053] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the description, claims, and drawings. Attached Figure Description

[0054] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with the embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0055] Figure 1 This is a flowchart illustrating an embodiment of the wellbore annular flow pressure drop detection method of the present invention;

[0056] Figure 2 A schematic diagram showing the comparison of electrical logging caliper data before and after processing for a reference well;

[0057] Figure 3a A graph showing the relationship between annular flow pressure drop and borehole enlargement factor under the condition that the concave height of the arc-shaped concave wellbore is 6m.

[0058] Figure 3b A graph showing the relationship between annular flow pressure drop and borehole enlargement factor under the condition that the concave surface height of the arc-shaped concave wellbore is 7m.

[0059] Figure 3c A graph showing the relationship between annular flow pressure drop and wellbore enlargement factor under the condition that the concave height of the arc-shaped concave wellbore is 8m.

[0060] Figure 3d A graph showing the relationship between annular flow pressure drop and wellbore enlargement factor under the condition of a concave surface height of 9m in an arc-shaped concave wellbore drilled;

[0061] Figure 3e A graph showing the relationship between annular flow pressure drop and wellbore enlargement factor under the condition of a concave surface height of 10m in an arc-shaped concave wellbore drilled;

[0062] Figure 3f A graph showing the relationship between annular flow pressure drop and wellbore enlargement factor under the condition of a concave surface height of 11m in an arc-shaped concave wellbore drilled;

[0063] Figure 3g A graph showing the relationship between annular flow pressure drop and wellbore enlargement factor under the condition of a concave surface height of 12m in an arc-shaped concave wellbore drilled;

[0064] Figure 4 This is a schematic diagram comparing the electrical logging caliper series data of the well to be logged before and after processing.

[0065] Figure 5 This is a schematic diagram of one embodiment of the wellbore annular flow pressure drop detection device of the present invention;

[0066] Figure 6 This is a schematic diagram of another embodiment of the wellbore annular flow pressure drop detection device of the present invention;

[0067] Figure 7 This is a schematic diagram of an embodiment of a wellbore annular flow pressure drop detection device according to the present invention. Detailed Implementation

[0068] The embodiments of the present invention will be described in detail below with reference to the accompanying drawings and examples, so that the process of how the present invention uses technical means to solve technical problems and achieve technical effects can be fully understood and implemented accordingly. It should be noted that, as long as there is no conflict, the various embodiments and features in the various embodiments of the present invention can be combined with each other, and the resulting technical solutions are all within the protection scope of the present invention.

[0069] Example 1

[0070] To address the aforementioned technical problems in the prior art, this invention provides a method for detecting the annular flow pressure drop in wellbore.

[0071] Figure 1 This is a flowchart of an embodiment of the wellbore annular flow pressure drop detection method of the present invention, as shown below. Figure 1 As shown, the method for detecting the annular flow pressure drop in this embodiment may specifically include the following steps:

[0072] 100. Obtain the series of electrical logging diameter data for the well to be logged;

[0073] In a specific implementation process, the electrical logging diameter series data of the well to be logged can be obtained from the monitoring data during the drilling process.

[0074] The logging caliper series data of the well to be logged includes at least the depth Hi′ of each logging point and the corresponding wellbore diameter value Dhi′, i=1~w, where w is the number of logging caliper series data.

[0075] 101. Fit the series of electrical logging diameter data of the well to be tested, process the irregular enlarged diameter section into the arc-shaped concave wellbore to be tested, and obtain the maximum diameter of the arc-shaped concave wellbore to be tested and the concave height of the arc-shaped concave wellbore to be tested.

[0076] In a specific implementation, the electrical logging data of the well to be logged can be fitted using the least squares method. Irregular enlarged well sections can be processed into arc-shaped concave wellbores to be logged, thus obtaining a fitting curve. Then, based on this fitting curve, the maximum well diameter and the concave height of the arc-shaped concave wellbore to be logged can be obtained.

[0077] 102. Determine the well diameter enlargement factor of the arc-shaped concave wellbore to be tested based on the maximum well diameter of the wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance;

[0078] Specifically, the maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested can be substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested.

[0079] The formula for calculating the magnification factor of the well to be logged is:

[0080] ηi′=(D ai (-Db') / Db';

[0081] Wherein, the η i ′ represents the wellbore enlargement factor for the i-th arc-shaped concave wellbore to be tested, where D ai ′ represents the maximum diameter of the arc-shaped concave wellbore to be tested, and D b ′ represents the diameter of the drill bit in the well to be measured.

[0082] 103. Input the well diameter enlargement factor of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested into the pre-constructed irregular wellbore annular flow pressure drop model of the reference well to calculate the irregular wellbore annular flow pressure drop of the well to be tested.

[0083] In a specific implementation process, an already developed oil well can be selected as a reference well to construct an irregular wellbore annular flow pressure drop model. This construction process may include the following steps:

[0084] (11) Obtain the series of electrical logging diameter data of the reference well;

[0085] In a specific implementation process, an already developed oil well can be used as a reference well, and the electrical logging caliper series data of the reference well can be obtained.

[0086] The reference well's logging caliper series data should include at least the depth Hi and the corresponding wellbore diameter D for each logging point. hi , i = 1 to n, where n is the number of well diameter data.

[0087] (12) Fit the series of electrical logging data of the reference well, process the irregular enlarged well section into a reference arc concave wellbore, and obtain the maximum well diameter and concave height of the reference arc concave wellbore.

[0088] In a specific implementation process, the electrical logging data of the reference well can be fitted using the least squares method. The irregular enlarged well section can be processed into a reference arc-shaped concave wellbore to obtain a fitting curve. Then, based on the fitting curve, the maximum well diameter and the concave height of the reference arc-shaped concave wellbore can be obtained.

[0089] (13) Determine the well diameter expansion factor of the reference arc concave well based on the maximum well diameter of the reference arc concave well and the drill bit diameter of the reference well obtained in advance;

[0090] Specifically, the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the pre-obtained reference well can be substituted into the preset formula for calculating the enlargement coefficient of the reference well to obtain the well diameter enlargement coefficient of the reference arc-shaped concave wellbore.

[0091] The formula for calculating the magnification factor of the reference well is:

[0092] η i =(D ai -D b ) / D b ;

[0093] Wherein, the η i D represents the wellbore enlargement factor for the i-th reference arc-shaped concave wellbore. ai The D represents the maximum diameter of the reference arc-shaped concave wellbore. b This indicates the drill bit diameter of the reference well.

[0094] (14) Based on the well diameter enlargement coefficient of the reference arc-shaped concave wellbore and the preset coefficient adjustment step size, generate the sample well diameter enlargement coefficient at the concave height of the reference arc-shaped concave wellbore.

[0095] In a specific implementation process, after obtaining the well diameter enlargement coefficient of the reference arc-shaped concave wellbore, it can be adjusted according to the preset coefficient adjustment step size, and both the well diameter enlargement coefficient of the reference arc-shaped concave wellbore and the adjusted well diameter enlargement coefficient are used as the sample well diameter enlargement coefficient.

[0096] Specifically, the preset coefficient adjustment step size can be 10%, that is, it can be gradually increased by 10% or decreased by 10% based on the well diameter enlargement coefficient of the reference arc-shaped concave wellbore. Then, both the well diameter enlargement coefficient of the reference arc-shaped concave wellbore and the adjusted well diameter enlargement coefficient are used as the sample well diameter enlargement coefficient.

[0097] In a specific implementation, the minimum well diameter enlargement factor for each sample can be 10%, and the maximum can be 100%.

[0098] (15) Based on the pre-acquired drilling data of the reference well and the preset drilling data, adjust the step size to generate sample drilling data at the concave height of the reference arc-shaped concave wellbore.

[0099] In a specific implementation process, after obtaining the drilling data of the reference well in advance, the drilling data can be adjusted according to the preset drilling data step size, and both the drilling data of the reference well and the adjusted drilling data are used as sample drilling data.

[0100] Among them, at least one of the following is obtained in advance: the outer diameter of the casing of the reference well, the density of the drilling fluid of the reference well, the plastic viscosity of the drilling fluid of the reference well, the dynamic shear force of the drilling fluid of the reference well, and the circulation displacement of the drilling fluid of the reference well.

[0101] The drilling data of the well to be logged includes at least one of the following: casing outer diameter value Dc, drilling fluid density value, drilling fluid plastic viscosity value, drilling fluid dynamic shear force value, and drilling fluid circulation displacement value; and the data type of the drilling data of the well to be logged is consistent with the data type of the drilling data of the reference well.

[0102] In a specific implementation, adjustments can be made to only one data point in the drilling data of the reference well, or to multiple data points in the drilling data of the reference well. For example, only the drilling fluid circulation displacement value of the reference well can be adjusted.

[0103] In a specific implementation, the drilling data adjustment step size can be 5, which can be based on the value corresponding to the drilling data of the reference well, plus or minus 5. The maximum value of the drilling fluid circulation displacement value of the reference well can be 50 L / s, and the minimum value can be 10 L / s.

[0104] (16) Input the concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient into a preset fluid flow numerical simulation model for calculation, and obtain the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore.

[0105] It should be noted that there may be multiple irregular wellbores in the well to be logged. Therefore, there are also multiple reference arc-shaped concave wellbores. The concave height of different reference arc-shaped concave wellbores may be the same or different. Therefore, in this embodiment, we can obtain the annular flow pressure drop of multiple reference wells under different sample drilling data corresponding to the concave height of each reference arc-shaped concave wellbore and different sample well diameter enlargement coefficients.

[0106] (17) Based on the irregular wellbore annular flow pressure drop of the reference well, construct the irregular wellbore annular flow pressure drop model of the reference well.

[0107] Specifically, an irregular wellbore annular flow pressure drop pattern of the reference wells can be drawn based on the irregular wellbore annular flow pressure drop of multiple reference wells as an irregular wellbore annular flow pressure drop model.

[0108] It should be noted that this embodiment is not limited to the irregular wellbore annular flow pressure drop version of the reference well. Figure 1 One approach is to use a functional relationship as a model for the pressure drop in the annulus flow of irregular wellbore.

[0109] In a specific implementation process, after obtaining the wellbore diameter enlargement factor, the concave height, and the drilling data of the well to be tested, the wellbore diameter enlargement factor, the concave height, and the drilling data of the well to be tested can be input into a pre-constructed irregular wellbore annular flow pressure drop model of a reference well for calculation, thereby obtaining the irregular wellbore annular flow pressure drop of the well to be tested.

[0110] In a specific implementation process, the drill bit diameter of the well to be logged is matched with the drill bit diameter of the reference well to ensure that the influencing factors between the irregular wellbore annular flow pressure drop of the well to be logged and the irregular wellbore annular flow pressure drop of the reference well are matched, thereby improving the accuracy of the irregular wellbore annular flow pressure drop of the well to be logged.

[0111] The wellbore annular flow pressure drop detection method of this embodiment fits the acquired electrical logging diameter series data of the well to be tested, processes the irregular enlarged diameter section into a test arc-shaped concave wellbore, and obtains the maximum diameter and concave height of the test arc-shaped concave wellbore. Based on the maximum diameter of the test arc-shaped concave wellbore and the pre-acquired drill bit diameter of the well to be tested, the diameter enlargement coefficient of the test arc-shaped concave wellbore is determined. Then, the diameter enlargement coefficient, the concave height of the test arc-shaped concave wellbore, and the drilling data of the well to be tested are input into a pre-constructed irregular wellbore annular flow pressure drop model of a reference well for calculation to obtain the irregular wellbore annular flow pressure drop of the well to be tested. This method realizes the rapid detection of the irregular wellbore annular flow pressure drop of the well to be tested based on the irregular wellbore annular flow pressure drop of the reference well, thus improving the detection efficiency of irregular wellbore annular flow pressure drop.

[0112] It should be noted that the method of this embodiment can be executed by a single device, such as a computer or server. The method of this embodiment can also be applied to a distributed scenario, where multiple devices cooperate to complete the task. In such a distributed scenario, one of these devices may execute only one or more steps of the method of this embodiment, and the multiple devices will interact with each other to complete the method.

[0113] Example 2

[0114] The technical solution of the present invention will be described below with reference to specific examples:

[0115] Step 1: Obtaining reference well parameters:

[0116] The following data are provided for a well in an onshore oilfield: casing outer diameter Dc = 177.8 mm, drill bit diameter Db = 215.9 mm, drilling fluid density ρm = 1.35 g / cm³, drilling fluid plastic viscosity μ = 15 mPa·s, drilling fluid dynamic shear force τm = 9 Pa, and drilling fluid circulation rate Qm = 30 L / s. The logging data for the reference well is shown in Table 1.

[0117] Table 1

[0118]

[0119]

[0120] Step 2: Reference well parameter processing:

[0121] The least squares method was used to fit the series of logging diameter data, and the irregular enlarged diameter section was processed into an arc-shaped concave wellbore, such as... Figure 2 As shown. Figure 2 This is a schematic diagram comparing the electrical logging data of a reference well before and after processing.

[0122] like Figure 2 As shown, after processing the electrical logging well diameter series data, this well section can be regarded as a combination of a reference arc-shaped concave well section and a regular well section. The concave height of the reference arc-shaped concave well section is 9m, the maximum well diameter is 291.5mm, and the well diameter expansion factor of the reference arc-shaped concave well section is η1 = (291.5-215.9) / 215.9 = 35%.

[0123] Line A represents the well diameter curve of the reference well before processing the electrical logging data series, while line B represents the well diameter curve of the reference well after processing the electrical logging data series.

[0124] Step 3: Reference well numerical simulation calculation:

[0125] The following parameters were used as references for the concave wellbore: concave height Ha1 = 9m, casing outer diameter Dc = 177.8mm, drilling fluid density ρm = 1.35g / cm3, drilling fluid plastic viscosity μm = 15mPa·s, drilling fluid dynamic shear force τm = 9Pa, and drilling fluid circulation rate Qm = 30L / s. These parameters were then substituted into CFD fluid flow numerical simulation software to calculate the annular flow pressure drop Pa1 of the concave wellbore section. Based on this calculation model and method, the annular flow pressure drop of the drilling fluid in the concave wellbore was calculated under different wellbore enlargement factors (10-100%, calculated every 10% change) and different drilling fluid circulation rates (generally, the minimum drilling fluid circulation rate is 10L / s, and the maximum circulation rate is 50L / s, calculated every 5 increments or decrements from Qm).

[0126] Step 4: Establish a reference well chart:

[0127] The above data were compiled to form a drilling fluid annular flow pressure drop chart for a concave wellbore with different wellbore enlargement factors (10%, 20%, 30%, 40%, 50%, 60%, 70%, 80%, 90%, 100%) and different drilling fluid circulation rates (10L / s, 15L / s, 20L / s, 25L / s, 30L / s, 35L / s, 40L / s, 45L / s, 50L / s) under different concave heights. Following the above method, the drilling fluid annular flow pressure drop charts for different concave heights (the number of concave heights j is taken within a certain fluctuation range based on the formation characteristics of this block; for this reference well, j is 6, 7, 8, 9, 10, 11, 12 meters) were calculated for different wellbore enlargement factors and different drilling fluid circulation rates, as shown in Figure 3.

[0128] in, Figure 3aThis is a graph showing the relationship between annular flow pressure drop and wellbore enlargement coefficient under the condition that the concave height of the arc-shaped concave wellbore is 6m.

[0129] Figure 3b This is a graph showing the relationship between annular flow pressure drop and wellbore enlargement coefficient under the condition that the concave height of the arc-shaped concave wellbore is 7m.

[0130] Figure 3c This is a graph showing the relationship between annular flow pressure drop and wellbore enlargement coefficient under the condition that the concave height of the arc-shaped concave wellbore is 8m.

[0131] Figure 3d This is a graph showing the relationship between annular flow pressure drop and wellbore enlargement coefficient under the condition that the concave height of the arc-shaped concave wellbore is 9m.

[0132] Figure 3e This is a graph showing the relationship between annular flow pressure drop and wellbore enlargement coefficient under the condition that the concave height of the arc-shaped concave wellbore is 10m.

[0133] Figure 3f This is a graph showing the relationship between annular flow pressure drop and wellbore enlargement coefficient under the condition that the concave height of the arc-shaped concave wellbore is 11m.

[0134] Figure 3g This is a graph showing the relationship between annular flow pressure drop and wellbore enlargement coefficient under the condition that the concave height of the arc-shaped concave wellbore is 12m.

[0135] Step 5: Obtaining Well Parameters

[0136] Obtain the electrical logging caliber series data of the well to be logged, which corresponds to the casing-drill bit size matching the drawing, including the casing outer diameter value D of a specific opening in an oil or gas well. c =177.8mm, drill bit diameter data D b =215.9mm, drilling fluid circulation displacement value Q m =35L / s, the series of logging diameter data for the well to be logged is shown in Table 2 below. Table 2 shows the series of logging diameter data for the well to be logged.

[0137] Table 2

[0138]

[0139] Step 6: Calculation of well parameters:

[0140] The least squares method was used to fit the logging diameter data, and the irregular enlarged well section was processed into a concave arc-shaped wellbore to be measured. The processed wellbore diagram is shown below. Figure 4 As shown. Figure 4This is a schematic diagram comparing the logging caliper series data of the well to be logged before and after processing. Line C represents the caliper curve of the reference well before logging caliper series data processing, and line D represents the caliper curve of the reference well after logging caliper series data processing.

[0141] from Figure 4 As can be seen, this wellbore section is a combination of one arc-shaped concave wellbore section to be tested and two regular wellbore sections. The maximum outer diameter D of the arc-shaped concave wellbore section to be tested... a1 =280mm, the concave height H of the arc-shaped concave well section to be measured a1 =8m, the wellbore enlargement factor η1′ of the arc-shaped concave well section to be tested is calculated by the following formula:

[0142] η1′=(D a1 ′-D b ′) / D b = (280-215.9) / 215.9 = 30%

[0143] Step 7: Calculate well chart query:

[0144] against Figure 4 The arc-shaped concave wellbore section shown is to be tested according to the concave height H of the arc-shaped concave wellbore section to be tested. a1 =8m, well diameter enlargement factor η1′ = 30% for the arc-shaped concave well section to be tested, drilling fluid circulation displacement value Q m =35L / s. Consult the chart to find the corresponding drilling fluid annular flow pressure drop P under this condition. a1 = 6200 Pa. The sum of the annular flow pressure drops of drilling fluid in all tested arc-shaped concave wellbore sections is

[0145] It should be noted that the concave height H of the arc-shaped concave wellbore section to be tested... ai ′、Well diameter magnification factor η of the arc-shaped concave wellbore section to be tested i ′、The drilling fluid circulation displacement value Q of the arc-shaped concave wellbore section to be tested m Points not on the curve of the drawing are processed by Lagrange linear interpolation.

[0146] Example 3

[0147] To address the aforementioned technical problems in the prior art, this invention provides a device for detecting the flow pressure drop in the wellbore annulus.

[0148] Figure 5 This is a schematic diagram of one embodiment of the wellbore annular flow pressure drop detection device of the present invention, as shown below. Figure 5As shown, the wellbore annular flow pressure drop detection device of this embodiment may include an acquisition module 50, a fitting module 51, a first determination module 52, and a second determination module 53.

[0149] The acquisition module 50 is used to acquire the series data of electrical logging diameter of the well to be logged;

[0150] The fitting module 51 is used to fit the series data of the electrical logging diameter of the well to be tested, process the irregular enlarged well section into the arc-shaped concave wellbore to be tested, and obtain the maximum well diameter and the concave height of the arc-shaped concave wellbore to be tested.

[0151] Specifically, the series of electrical logging data of the well to be tested can be fitted based on the least squares method, and the irregular enlarged well section can be processed into the arc-shaped concave wellbore to be tested.

[0152] The first determining module 52 is used to determine the well diameter expansion factor of the arc-shaped concave wellbore to be tested based on the maximum well diameter of the arc-shaped concave wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance.

[0153] Specifically, the maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested can be substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested.

[0154] The formula for calculating the magnification factor of the well to be logged is:

[0155] η i ′=(D ai ′-D b ′) / D b ′;

[0156] Wherein, the η i ′ represents the wellbore enlargement factor for the i-th arc-shaped concave wellbore to be tested, where D ai ′ represents the maximum diameter of the arc-shaped concave wellbore to be tested, and D b ′ represents the diameter of the drill bit in the well to be measured.

[0157] The second determining module 53 is used to input the well diameter enlargement coefficient of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested into a pre-constructed irregular wellbore annular flow pressure drop model of a reference well to calculate the irregular wellbore annular flow pressure drop of the well to be tested; wherein, the drill bit diameter of the well to be tested is matched with the drill bit diameter of the reference well.

[0158] The wellbore annular flow pressure drop detection device of this embodiment fits the acquired electrical logging diameter series data of the well to be tested, processes the irregular enlarged diameter section into a test arc-shaped concave wellbore, and obtains the maximum diameter and concave height of the test arc-shaped concave wellbore. Based on the maximum diameter of the test arc-shaped concave wellbore and the pre-acquired drill bit diameter of the well to be tested, the diameter enlargement coefficient of the test arc-shaped concave wellbore is determined. Then, the diameter enlargement coefficient, the concave height of the test arc-shaped concave wellbore, and the drilling data of the well to be tested are input into a pre-constructed irregular wellbore annular flow pressure drop model of a reference well for calculation to obtain the irregular wellbore annular flow pressure drop of the well to be tested. This realizes the rapid detection of the irregular wellbore annular flow pressure drop of the well to be tested based on the irregular wellbore annular flow pressure drop of the reference well, thus improving the detection efficiency of irregular wellbore annular flow pressure drop.

[0159] Figure 6 This is a schematic diagram of another embodiment of the wellbore annular flow pressure drop detection device of the present invention, as shown below. Figure 6 As shown, the wellbore annular flow pressure drop detection device of this embodiment is... Figure 5 Based on the illustrated embodiment, it may further include a first adjustment module 54, a second adjustment module 55, and a construction module 56.

[0160] The acquisition module 50 is also used to acquire electrical logging caliper series data of the reference well;

[0161] The fitting module 51 is also used to fit the electrical logging diameter series data of the reference well, process the irregular enlarged well section into a reference arc concave wellbore, and obtain the maximum well diameter and concave height of the reference arc concave wellbore.

[0162] The first determining module 52 is further configured to determine the well diameter enlargement factor of the reference arc-shaped concave wellbore based on the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the reference well obtained in advance;

[0163] The first adjustment module 54 is further configured to generate a sample well diameter expansion coefficient at the concave height of the reference arc-shaped concave wellbore based on the well diameter expansion coefficient of the reference arc-shaped concave wellbore and a preset coefficient adjustment step size; wherein, the sample well diameter expansion coefficient includes the well diameter expansion coefficient of the reference arc-shaped concave wellbore and the adjusted well diameter expansion coefficient.

[0164] The second adjustment module 55 is further configured to adjust the step size based on the pre-acquired drilling data of the reference well and the preset drilling data, and generate sample drilling data at the concave height of the reference arc-shaped concave wellbore; wherein, the sample drilling data includes the drilling data of the reference well and the adjusted drilling data;

[0165] The second determining module 53 inputs the concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient into a preset fluid flow numerical simulation model for calculation, and obtains the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore.

[0166] The construction module 56 is also used to construct an irregular wellbore annular flow pressure drop model of the reference well based on the irregular wellbore annular flow pressure drop of the reference well.

[0167] In one specific implementation process, the drilling data of the reference well includes at least one of the following: the outer diameter of the casing of the reference well, the density of the drilling fluid of the reference well, the plastic viscosity of the drilling fluid of the reference well, the dynamic shear force of the drilling fluid of the reference well, and the circulation displacement of the drilling fluid of the reference well.

[0168] The drilling data of the well to be logged includes at least one of the following: casing outer diameter value Dc, drilling fluid density value, drilling fluid plastic viscosity value, drilling fluid dynamic shear force value, and drilling fluid circulation displacement value; and the data type of the drilling data of the well to be logged is consistent with the data type of the drilling data of the reference well.

[0169] The apparatus in the above embodiments is used to implement the corresponding methods in the foregoing embodiments. The specific implementation scheme can be found in the methods described in the foregoing embodiments and the relevant descriptions in the method embodiments, and has the beneficial effects of the corresponding method embodiments, which will not be repeated here.

[0170] Example 4

[0171] To address the aforementioned technical problems in the prior art, this invention provides a device for detecting the flow pressure drop in the wellbore annulus.

[0172] Figure 7 This is a schematic diagram of an embodiment of a wellbore annular flow pressure drop detection device according to the present invention, as shown below. Figure 7 As shown, the device may include a processor 1010 and a memory 1020. As those skilled in the art will understand, the device may also include an input / output interface 1030, a communication interface 1040, and a bus 1050. The processor 1010, memory 1020, input / output interface 1030, and communication interface 1040 are interconnected internally via the bus 1050.

[0173] The processor 1010 can be implemented using a general-purpose CPU (Central Processing Unit), microprocessor, application-specific integrated circuit (ASIC), or one or more integrated circuits, and is used to execute relevant programs to implement the technical solutions provided in the embodiments of this specification.

[0174] The memory 1020 can be implemented in the form of ROM (Read Only Memory), RAM (Random Access Memory), static storage device, dynamic storage device, etc. The memory 1020 can store the operating system and other applications. When the technical solutions provided in the embodiments of this specification are implemented by software or firmware, the relevant program code is stored in the memory 1020 and is called and executed by the processor 1010.

[0175] The input / output interface 1030 is used to connect input / output modules to realize information input and output. Input / output modules can be configured as components within the device (not shown in the figure) or externally connected to the device to provide corresponding functions. Input devices may include keyboards, mice, touchscreens, microphones, various sensors, etc., while output devices may include displays, speakers, vibrators, indicator lights, etc.

[0176] The communication interface 1040 is used to connect a communication module (not shown in the figure) to enable communication between this device and other devices. The communication module can communicate via wired means (such as USB, Ethernet cable, etc.) or wireless means (such as mobile network, WIFI, Bluetooth, etc.).

[0177] Bus 1050 includes a pathway for transmitting information between various components of the device, such as processor 1010, memory 1020, input / output interface 1030, and communication interface 1040.

[0178] It should be noted that although the above-described device only shows the processor 1010, memory 1020, input / output interface 1030, communication interface 1040, and bus 1050, in specific implementations, the device may also include other components necessary for normal operation. Furthermore, those skilled in the art will understand that the above-described device may only include the components necessary for implementing the embodiments of this specification, and not necessarily all the components shown in the figures.

[0179] The detection device for the distribution information of organic shale clay provided in this embodiment of the invention stores a computer program in its memory. When the computer program is executed by the processor, it performs the following steps:

[0180] Obtain a series of electrical logging diameter data for the well to be logged;

[0181] The series of electrical logging data of the well to be tested are fitted, the irregular enlarged well section is processed into the arc-shaped concave wellbore to be tested, and the maximum well diameter and the concave height of the arc-shaped concave wellbore to be tested are obtained.

[0182] The well diameter enlargement factor of the arc-shaped concave wellbore to be tested is determined based on the maximum well diameter of the wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance.

[0183] The wellbore enlargement factor of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested are input into the pre-constructed irregular wellbore annular flow pressure drop model of the reference well for calculation to obtain the irregular wellbore annular flow pressure drop of the well to be tested; wherein, the drill bit diameter of the well to be tested is matched with the drill bit diameter of the reference well.

[0184] Furthermore, when a computer program is executed by a processor, it can also perform the following steps:

[0185] Obtain a series of electrical logging caliper data for the reference well;

[0186] The electrical logging data of the reference well are fitted to form an irregular enlarged well section into a reference arc-shaped concave wellbore, and the maximum well diameter and concave height of the reference arc-shaped concave wellbore are obtained.

[0187] The well diameter enlargement factor of the reference arc-shaped concave wellbore is determined based on the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the reference well obtained in advance.

[0188] Based on the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the preset coefficient adjustment step size, a sample wellbore enlargement coefficient is generated at the concave height of the reference arc-shaped concave wellbore; wherein, the sample wellbore enlargement coefficient includes the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the adjusted wellbore enlargement coefficient.

[0189] Based on the pre-acquired drilling data of the reference well and the preset drilling data adjustment step size, sample drilling data at the concave height of the reference arc-shaped concave wellbore is generated; wherein, the sample drilling data includes the drilling data of the reference well and the adjusted drilling data;

[0190] The concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient are input into a preset fluid flow numerical simulation model for calculation, to obtain the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore.

[0191] Based on the irregular wellbore annular flow pressure drop of the reference well, an annular flow pressure drop model of the reference well is constructed.

[0192] Furthermore, the drilling data of the reference well includes at least one of the following: the outer diameter of the casing of the reference well, the density of the drilling fluid of the reference well, the plastic viscosity of the drilling fluid of the reference well, the dynamic shear force of the drilling fluid of the reference well, and the circulation displacement of the drilling fluid of the reference well.

[0193] The drilling data of the well to be logged includes at least one of the following: casing outer diameter value Dc, drilling fluid density value, drilling fluid plastic viscosity value, drilling fluid dynamic shear force value, and drilling fluid circulation displacement value; and the data type of the drilling data of the well to be logged is consistent with the data type of the drilling data of the reference well.

[0194] Furthermore, when a computer program is executed by a processor, it can also perform the following steps:

[0195] The maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested are substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested.

[0196] The formula for calculating the magnification factor of the well to be logged is:

[0197] η i ′=(D ai ′-D b ′) / D b ′;

[0198] Wherein, the η i ′ represents the wellbore enlargement factor for the i-th arc-shaped concave wellbore to be tested, where D ai ′ represents the maximum diameter of the arc-shaped concave wellbore to be tested, and D b ′ represents the diameter of the drill bit in the well to be measured.

[0199] Furthermore, when a computer program is executed by a processor, it can also perform the following steps:

[0200] Based on the least squares method, the series of electrical logging diameter data of the well to be measured are fitted, and the irregular enlarged diameter section is processed into the arc-shaped concave wellbore to be measured.

[0201] Example 5

[0202] To address the aforementioned technical problems in the prior art, embodiments of the present invention provide a storage medium.

[0203] The storage medium provided in this embodiment of the invention stores a computer program, which, when executed by a processor, performs the following steps.

[0204] Obtain a series of electrical logging diameter data for the well to be logged;

[0205] The series of electrical logging data of the well to be tested are fitted, the irregular enlarged well section is processed into the arc-shaped concave wellbore to be tested, and the maximum well diameter and the concave height of the arc-shaped concave wellbore to be tested are obtained.

[0206] The well diameter enlargement factor of the arc-shaped concave wellbore to be tested is determined based on the maximum well diameter of the wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance.

[0207] The wellbore enlargement factor of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested are input into the pre-constructed irregular wellbore annular flow pressure drop model of the reference well for calculation to obtain the irregular wellbore annular flow pressure drop of the well to be tested; wherein, the drill bit diameter of the well to be tested is matched with the drill bit diameter of the reference well.

[0208] Furthermore, when a computer program is executed by a processor, it can also perform the following steps:

[0209] Obtain a series of electrical logging caliper data for the reference well;

[0210] The electrical logging data of the reference well are fitted to form an irregular enlarged well section into a reference arc-shaped concave wellbore, and the maximum well diameter and concave height of the reference arc-shaped concave wellbore are obtained.

[0211] The well diameter enlargement factor of the reference arc-shaped concave wellbore is determined based on the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the reference well obtained in advance.

[0212] Based on the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the preset coefficient adjustment step size, a sample wellbore enlargement coefficient is generated at the concave height of the reference arc-shaped concave wellbore; wherein, the sample wellbore enlargement coefficient includes the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the adjusted wellbore enlargement coefficient.

[0213] Based on the pre-acquired drilling data of the reference well and the preset drilling data adjustment step size, sample drilling data at the concave height of the reference arc-shaped concave wellbore is generated; wherein, the sample drilling data includes the drilling data of the reference well and the adjusted drilling data;

[0214] The concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient are input into a preset fluid flow numerical simulation model for calculation, to obtain the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore.

[0215] Based on the irregular wellbore annular flow pressure drop of the reference well, an annular flow pressure drop model of the reference well is constructed.

[0216] Furthermore, the drilling data of the reference well includes at least one of the following: the outer diameter of the casing of the reference well, the density of the drilling fluid of the reference well, the plastic viscosity of the drilling fluid of the reference well, the dynamic shear force of the drilling fluid of the reference well, and the circulation displacement of the drilling fluid of the reference well.

[0217] The drilling data of the well to be logged includes at least one of the following: casing outer diameter value Dc, drilling fluid density value, drilling fluid plastic viscosity value, drilling fluid dynamic shear force value, and drilling fluid circulation displacement value; and the data type of the drilling data of the well to be logged is consistent with the data type of the drilling data of the reference well.

[0218] Furthermore, when a computer program is executed by a processor, it can also perform the following steps:

[0219] The maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested are substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested.

[0220] The formula for calculating the magnification factor of the well to be logged is:

[0221] η i ′=(D ai ′-D b ′) / D b ′;

[0222] Wherein, the η i ′ represents the wellbore enlargement factor for the i-th arc-shaped concave wellbore to be tested, where D ai ′ represents the maximum diameter of the arc-shaped concave wellbore to be tested, and D b ′ represents the diameter of the drill bit in the well to be measured.

[0223] Furthermore, when a computer program is executed by a processor, it can also perform the following steps:

[0224] Based on the least squares method, the series of electrical logging diameter data of the well to be measured are fitted, and the irregular enlarged diameter section is processed into the arc-shaped concave wellbore to be measured.

[0225] It is understood that the same or similar parts in the above embodiments can be referred to each other, and the contents not described in detail in some embodiments can be referred to the same or similar contents in other embodiments.

[0226] It should be noted that in the description of this invention, the terms "first," "second," etc., are used for descriptive purposes only and should not be construed as indicating or implying relative importance. Furthermore, in the description of this invention, unless otherwise stated, "a plurality of" means at least two.

[0227] Any process or method description in the flowchart or otherwise herein can be understood as representing a module, segment, or portion of code comprising one or more executable instructions for implementing a particular logical function or process, and the scope of the preferred embodiments of the invention includes additional implementations in which functions may be performed not in the order shown or discussed, including substantially simultaneously or in reverse order depending on the functions involved, as will be understood by those skilled in the art to which embodiments of the invention pertain.

[0228] It should be understood that various parts of the present invention can be implemented in hardware, software, firmware, or a combination thereof. In the above embodiments, multiple steps or methods can be implemented in software or firmware stored in memory and executed by a suitable instruction execution system. For example, if implemented in hardware, as in another embodiment, it can be implemented using any one or a combination of the following techniques known in the art: discrete logic circuits having logic gates for implementing logical functions on data signals, application-specific integrated circuits (ASICs) having suitable combinational logic gates, programmable gate arrays (PGAs), field-programmable gate arrays (FPGAs), etc.

[0229] Those skilled in the art will understand that all or part of the steps of the methods described in the above embodiments can be implemented by a program instructing related hardware. The program can be stored in a computer-readable storage medium, and when executed, it includes one or a combination of the steps of the method embodiments.

[0230] Furthermore, the functional units in the various embodiments of the present invention can be integrated into a processing module, or each unit can exist physically separately, or two or more units can be integrated into a module. The integrated module can be implemented in hardware or as a software functional module. If the integrated module is implemented as a software functional module and sold or used as an independent product, it can also be stored in a computer-readable storage medium.

[0231] The storage media mentioned above can be read-only memory, disk, or optical disk, etc.

[0232] In the description of this specification, references to terms such as "one embodiment," "some embodiments," "example," "specific example," or "some examples," etc., indicate that a specific feature, structure, material, or characteristic described in connection with that embodiment or example is included in at least one embodiment or example of the invention. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described may be combined in any suitable manner in one or more embodiments or examples.

[0233] While the embodiments disclosed in this invention are as described above, the content is merely for the purpose of facilitating understanding of the invention and is not intended to limit the invention. Any person skilled in the art to which this invention pertains may make any modifications and changes in form and detail of the implementation without departing from the spirit and scope disclosed herein; however, the scope of protection of this invention shall still be determined by the scope defined in the appended claims.

Claims

1. A method for detecting the pressure drop in the annulus flow of a wellbore, characterized in that, include: Obtain a series of electrical logging diameter data for the well to be logged; The series of electrical logging data of the well to be tested are fitted, the irregular enlarged well section is processed into the arc-shaped concave wellbore to be tested, and the maximum well diameter and the concave height of the arc-shaped concave wellbore to be tested are obtained. The well diameter enlargement factor of the arc-shaped concave wellbore to be tested is determined based on the maximum well diameter of the wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance. The wellbore diameter enlargement factor of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested are input into the pre-constructed irregular wellbore annular flow pressure drop model of the reference well for calculation to obtain the irregular wellbore annular flow pressure drop of the well to be tested; wherein, the drill bit diameter of the well to be tested is matched with the drill bit diameter of the reference well. The construction process for calculating the pressure drop in the irregular wellbore annulus flow of the reference well includes: Obtain a series of electrical logging caliper data for the reference well; The electrical logging data of the reference well are fitted to form an irregular enlarged well section into a reference arc-shaped concave wellbore, and the maximum well diameter and concave height of the reference arc-shaped concave wellbore are obtained. The well diameter enlargement factor of the reference arc-shaped concave wellbore is determined based on the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the reference well obtained in advance. Based on the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the preset coefficient adjustment step size, a sample wellbore enlargement coefficient is generated at the concave height of the reference arc-shaped concave wellbore; wherein, the sample wellbore enlargement coefficient includes the wellbore enlargement coefficient of the reference arc-shaped concave wellbore and the adjusted wellbore enlargement coefficient. Based on the pre-acquired drilling data of the reference well and the preset drilling data adjustment step size, sample drilling data at the concave height of the reference arc-shaped concave wellbore is generated; wherein, the sample drilling data includes the drilling data of the reference well and the adjusted drilling data; The concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient are input into a preset fluid flow numerical simulation model for calculation, to obtain the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore. Based on the irregular wellbore annular flow pressure drop of the reference well, an irregular wellbore annular flow pressure drop model of the reference well is constructed; Based on the maximum wellbore diameter of the arc-shaped concave well to be tested and the pre-obtained drill bit diameter of the well to be tested, the wellbore diameter enlargement factor of the arc-shaped concave well to be tested is determined, including: The maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested are substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested. The formula for calculating the magnification factor of the well to be logged is: ηi′=(Dai′-Db′) / Db′; Wherein, ηi′ represents the well diameter enlargement coefficient of the i-th arc-shaped concave wellbore to be tested, Dai′ represents the maximum well diameter of the arc-shaped concave wellbore to be tested, and Db′ represents the drill bit diameter of the well to be tested.

2. The method for detecting the annular flow pressure drop in a wellbore according to claim 1, characterized in that, The drilling data of the reference well includes at least one of the following: the outer diameter of the casing of the reference well, the density of the drilling fluid of the reference well, the plastic viscosity of the drilling fluid of the reference well, the dynamic shear force of the drilling fluid of the reference well, and the circulation displacement of the drilling fluid of the reference well. The drilling data of the well to be logged includes at least one of the following: casing outer diameter value Dc, drilling fluid density value, drilling fluid plastic viscosity value, drilling fluid dynamic shear force value, and drilling fluid circulation displacement value; and the data type of the drilling data of the well to be logged is consistent with the data type of the drilling data of the reference well.

3. The method for detecting the annular flow pressure drop in a wellbore according to claim 1, characterized in that, Fitting the electrical logging caliper series data of the well to be logged, and processing the irregular enlarged caliper section into the arc-shaped concave wellbore to be logged, including: Based on the least squares method, the series of electrical logging diameter data of the well to be measured are fitted, and the irregular enlarged diameter section is processed into the arc-shaped concave wellbore to be measured.

4. A device for detecting wellbore annular flow pressure drop for implementing the method for detecting wellbore annular flow pressure drop according to any one of claims 1-3, characterized in that, include: The acquisition module is used to acquire a series of electrical logging diameter data for the well to be logged; The fitting module is used to fit the series of electrical logging diameter data of the well to be tested, process the irregular enlarged diameter section into the arc-shaped concave wellbore to be tested, and obtain the maximum diameter of the arc-shaped concave wellbore to be tested and the concave height of the arc-shaped concave wellbore to be tested. The first determining module is used to determine the well diameter enlargement factor of the arc-shaped concave wellbore to be tested based on the maximum well diameter of the wellbore to be tested and the drill bit diameter of the well to be tested obtained in advance. The second determining module is used to input the well diameter enlargement factor of the arc-shaped concave wellbore to be tested, the concave height of the arc-shaped concave wellbore to be tested, and the drilling data of the well to be tested into a pre-constructed irregular wellbore annular flow pressure drop model of a reference well to calculate the irregular wellbore annular flow pressure drop of the well to be tested; wherein, the drill bit diameter of the well to be tested is matched with the drill bit diameter of the reference well; It also includes a first adjustment module, a second adjustment module, and a construction module; The acquisition module is also used to acquire electrical logging caliper series data of the reference well; The fitting module is also used to fit the electrical logging diameter series data of the reference well, process the irregular enlarged well section into a reference arc-shaped concave wellbore, and obtain the maximum well diameter and concave height of the reference arc-shaped concave wellbore. The first determining module is further configured to determine the well diameter enlargement factor of the reference arc-shaped concave wellbore based on the maximum well diameter of the reference arc-shaped concave wellbore and the drill bit diameter of the reference well obtained in advance; The first adjustment module is further configured to generate a sample well diameter expansion coefficient at the concave height of the reference arc-shaped concave wellbore based on the well diameter expansion coefficient of the reference arc-shaped concave wellbore and a preset coefficient adjustment step size; wherein, the sample well diameter expansion coefficient includes the well diameter expansion coefficient of the reference arc-shaped concave wellbore and the adjusted well diameter expansion coefficient. The second adjustment module is further configured to adjust the step size based on the pre-acquired drilling data of the reference well and the preset drilling data, and generate sample drilling data at the concave height of the reference arc-shaped concave wellbore; wherein, the sample drilling data includes the drilling data of the reference well and the adjusted drilling data; The second determining module inputs the concave height of the reference arc-shaped concave wellbore, the sample drilling data, and the sample well diameter enlargement coefficient into a preset fluid flow numerical simulation model for calculation, and obtains the irregular wellbore annular flow pressure drop of multiple reference wells under different sample drilling data and different sample well diameter enlargement coefficients corresponding to the concave height of the reference arc-shaped concave wellbore. The construction module is also used to construct an irregular wellbore annular flow pressure drop model of the reference well based on the irregular wellbore annular flow pressure drop of the reference well. The first determining module is further configured to: The maximum well diameter of the arc-shaped concave well to be tested and the drill bit diameter of the well to be tested are substituted into the preset formula for calculating the magnification factor of the well to be tested to obtain the well diameter magnification factor of the arc-shaped concave well to be tested. The formula for calculating the magnification factor of the well to be logged is: ηi′=(Dai′-Db′) / Db′; Wherein, ηi′ represents the well diameter enlargement coefficient of the i-th arc-shaped concave wellbore to be tested, Dai′ represents the maximum well diameter of the arc-shaped concave wellbore to be tested, and Db′ represents the drill bit diameter of the well to be tested.

5. A device for detecting the pressure drop in the annulus flow of a wellbore, characterized in that, Including memory and processor; The memory stores a computer program, which, when executed by a processor, implements the steps of the wellbore annular flow pressure drop detection method as described in any one of claims 1 to 3.

6. A storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by the processor, it implements the steps of the wellbore annular flow pressure drop detection method as described in any one of claims 1 to 3.

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