Wellbore cleaning cycle time optimization method and device, electronic equipment and medium

Abstract

The embodiment of the invention discloses a borehole cleaning cycle time optimization method and device, electronic equipment and a medium. The method comprises the following steps: determining drilling data when a target borehole is cleaned; the drilling data comprises borehole size, drilling fluid displacement, drilling fluid density and drill stem rotating speed; according to the drilling data, the drilling fluid annulus return velocity vector sum and the rock debris settling velocity are determined, and whether the drilling data meet the target borehole cleaning requirement or not is determined according to the drilling fluid annulus return velocity vector sum and the rock debris settling velocity; and when the drilling data meet the target borehole cleaning requirement, the borehole cleaning target circulation time of a target borehole under the maximum annulus rock debris concentration condition is determined according to the drilling data. By adopting the technical scheme of the embodiment of the invention, under the condition that the measurement data of the annulus pressure while drilling can be obtained, the optimal analysis of the drilling fluid displacement, the drilling column rotating speed and the drilling column cycle time in the drilling process is realized, and the borehole cleaning time is saved on the premise of ensuring the drilling safety.

Description

Technical Field

[0001] The embodiments of the present invention relate to the technical field of oil and gas drilling safety monitoring, and in particular to a method, device, electronic equipment and medium for optimizing wellbore cleaning cycle time. Background Art

[0002] Poor hole cleaning during oil and gas drilling can lead to high friction and torque, long circulation, frequent reaming, and in severe cases, complex accidents such as pipe sticking, well filling and sidetracking. Therefore, adopting reasonable drilling parameters and construction procedures to promote the timely return of formation broken cuttings to the wellbore is of great significance for improving drilling speed, shortening drilling cycle, and ensuring drilling safety.

[0003] With the development of downhole parameter measurement technology, the use of annular pressure measurement data while drilling to monitor wellbore cleaning has become increasingly popular. However, the existing wellbore cleaning evaluation methods based on annular pressure while drilling still have certain problems, such as: the annular pressure parameters use theoretical technology instead of measured data, which affects the accuracy of the calculation results, and the wellbore cleaning parameters are not optimized and the wellbore cleaning cycle time is not optimized. Summary of the invention

[0004] The embodiments of the present invention provide a method, device, electronic device and storage medium for optimizing the cycle time of wellbore cleaning, so as to optimize and analyze the displacement, rotation speed and column driving cycle time during the drilling process, and save drilling time while ensuring the safety of drilling.

[0005] In a first aspect, an embodiment of the present invention provides a method for optimizing a wellbore cleaning cycle time, comprising:

[0006] Determine the drilling data when the target wellbore is cleaned; the drilling data includes wellbore size, drilling fluid displacement, drilling fluid density and drill string rotation speed;

[0007] Determine the drilling fluid annular return velocity vector sum and the cuttings settling velocity according to the drilling data, and determine whether the drilling data meets the target wellbore cleaning requirements according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity;

[0008] When the drilling data meets the target wellbore cleaning requirement, a target wellbore cleaning cycle time of the target wellbore under the condition of maximum annular cuttings concentration is determined according to the drilling data.

[0009] In a second aspect, an embodiment of the present invention further provides a wellbore cleaning cycle time optimization device, comprising:

[0010] A drilling data determination module is used to determine the drilling data when the target wellbore is cleaned; the drilling data includes wellbore size, drilling fluid displacement, drilling fluid density and drill string rotation speed;

[0011] A cleaning requirement determination module, used to determine the drilling fluid annular return velocity vector sum and the cuttings settling velocity according to the drilling data, and determine whether the drilling data meets the target wellbore cleaning requirement according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity;

[0012] The cycle time determination module is used to determine the target cycle time of the target wellbore cleaning under the condition of maximum annular cuttings concentration according to the drilling data when the drilling data meets the target wellbore cleaning requirements.

[0013] In a third aspect, an embodiment of the present invention further provides an electronic device, the electronic device comprising:

[0014] one or more processors;

[0015] A storage device for storing one or more programs;

[0016] When the one or more programs are executed by the one or more processors, the one or more processors implement the wellbore cleaning cycle time optimization method described in any embodiment of the present invention.

[0017] In a fourth aspect, an embodiment of the present invention further provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the wellbore cleaning cycle time optimization method described in any embodiment of the present invention.

[0018] The embodiment of the present invention provides a method, device, electronic device and storage medium for optimizing the wellbore cleaning cycle time, by determining the drilling data for cleaning the target wellbore; the drilling data includes wellbore size, drilling fluid displacement, drilling fluid density and drill string rotation speed; the drilling fluid annular return velocity vector sum and cuttings settling velocity are determined based on the drilling data, and whether the drilling data meets the target wellbore cleaning requirements is determined based on the drilling fluid annular return velocity vector sum and cuttings settling velocity; when the drilling data meets the target wellbore cleaning requirements, the target wellbore cleaning cycle time under the condition of maximum annular cuttings concentration is determined based on the drilling data. By adopting the technical solution of the embodiment of the present invention, under the condition that the annular pressure measurement data can be obtained while drilling, the drilling fluid displacement, drill string rotation speed and column completion cycle time during the drilling process can be optimized and analyzed, so as to save the wellbore cleaning time under the premise of ensuring drilling safety. BRIEF DESCRIPTION OF THE DRAWINGS

[0019] Other features, objects and advantages of the present invention will become more apparent by reading the detailed description of non-limiting embodiments made with reference to the following drawings. The drawings are only for the purpose of illustrating preferred embodiments and are not to be considered as limiting the present invention. Also, the same reference symbols are used throughout the drawings to represent the same parts. In the drawings:

[0020] Figure 1 is a flow chart of a method for optimizing a wellbore cleaning cycle time provided in an embodiment of the present invention;

[0021] Figure 2 is a flow chart of another method for optimizing wellbore cleaning cycle time provided in an embodiment of the present invention;

[0022] Figure 3 is a structural schematic diagram of a wellbore cleaning cycle time optimization device provided in an embodiment of the present invention;

[0023] Figure 4 It is a structural schematic diagram of an electronic device provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0024] The present invention will be further described in detail below in conjunction with the accompanying drawings and embodiments. It is to be understood that the specific embodiments described herein are only used to explain the present invention, rather than to limit the present invention. It should also be noted that, for ease of description, only parts related to the present invention, rather than all structures, are shown in the accompanying drawings.

[0025] Before discussing the exemplary embodiments in more detail, it should be mentioned that some exemplary embodiments are described as processes or methods depicted as flow charts. Although the flow charts describe the operations (or steps) as sequential processes, many of the operations (or steps) therein can be implemented in parallel, concurrently or simultaneously. In addition, the order of the operations can be rearranged. The process can be terminated when its operation is completed, but can also have additional steps not included in the accompanying drawings. The process can correspond to a method, function, procedure, subroutine, subprogram, etc.

[0026] Among them, the acquisition, storage, use and processing of data in the technical solution of this application are in compliance with the relevant provisions of national laws and regulations.

[0027] Figure 1 : is a flow chart of a method for optimizing a borehole cleaning cycle time provided in an embodiment of the present invention. This embodiment is applicable to the case of optimizing a borehole cleaning cycle time. The method of this embodiment can be executed by a borehole cleaning cycle time optimization device, which can be implemented in hardware and / or software. The device can be configured in a server for optimizing a borehole cleaning cycle time. The method specifically includes the following steps:

[0028] S110, determining drilling data when the target wellbore is clean.

[0029] When determining the borehole cleaning cycle time, it is necessary to first obtain the drilling data during borehole cleaning, and the drilling data includes but is not limited to borehole size, drilling fluid displacement, drilling fluid density, and drill string rotation speed. Different numerical results of drilling data will affect the cycle time during borehole cleaning; for example, if the drilling fluid displacement is small, the borehole cleaning time will be shorter; but for loose formations, the drilling fluid displacement should not be too large to avoid scouring the well wall and causing the well wall to become unstable. In the embodiment of the present invention, the drilling data is optimized and adjusted to optimize the cycle time of borehole cleaning on the basis of drilling safety and the ability to complete borehole cleaning.

[0030] S120, determining the drilling fluid annular return velocity vector sum and the cuttings settling velocity according to the drilling data, and determining whether the drilling data meets the target wellbore cleaning requirements according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity.

[0031] The greater the drilling fluid annular velocity, the easier it is for cuttings to return, and the harder it is for a cuttings bed to form in the wellbore; however, if the annular velocity is too high, the wellbore wall will be eroded, causing the wellbore wall to collapse, and cuttings will be mixed, affecting the quality of cuttings logging. In the embodiment of the present invention, the vector sum of the drilling fluid annular velocity is obtained by superimposing the axial velocity of the drilling fluid and the circumferential velocity of the drilling fluid.

[0032] As an optional but non-limiting implementation, the determining of the drilling fluid annular return velocity vector sum based on the drilling data includes but is not limited to steps A1-A3:

[0033] Step A1: Determine the axial flow velocity of the drilling fluid according to the drilling fluid displacement.

[0034] Step A2: Determine the circumferential flow rate of the drilling fluid according to the drill string rotation speed.

[0035] Step A3: vector superposition of the drilling fluid axial flow velocity and the drilling fluid circumferential flow velocity to determine the drilling fluid annular return velocity vector sum.

[0036] Among them, the axial flow velocity of the drilling fluid is calculated according to the drilling fluid displacement, and the calculation formula of the axial flow velocity of the drilling fluid along the drill string is:

[0037]

[0038] The circumferential velocity of the drilling fluid is calculated based on the drill string rotation speed. The calculation formula for the circumferential velocity of the drilling fluid caused by the drill string rotation is:

[0039]

[0040] The calculated drilling fluid axial velocity and axial velocity are vector-superimposed to obtain the drilling fluid annular velocity vector sum. The calculation formula for the drilling fluid annular return velocity vector sum is:

[0041]

[0042] Among them, V a represents the axial velocity of drilling fluid, m / s; Q is the displacement of drilling fluid, m 3 / s;D h is the borehole diameter, m; D p is the drill string diameter, m; V tp Characterizes the circumferential flow velocity of the drilling fluid, m / s; RPM is the drill string speed, rev / min; eff is the efficiency coefficient of the drilling fluid flow driven by the drill string rotation, generally taken as 0.25; V at Characterizes the drilling fluid annulus return velocity vector, m / s.

[0043] The rock cuttings settling velocity refers to the settling velocity of the rock cuttings relative to the mud under the action of natural gravity. The rock cuttings settling velocity is not only related to the flow pattern of the liquid flow, but also to the particle settling flow pattern. When the rock cuttings particles sink, the downstream tail streamline moves smoothly without bypassing, and the settling flow pattern is laminar flow, otherwise it is plain flow; there is a transitional settling flow range between laminar flow and plain flow.

[0044] As an optional but non-limiting implementation, the determining of the cuttings settling velocity based on the drilling data includes but is not limited to steps B1-B2:

[0045] Step B1: Determine the particle Reynolds number of the rock cuttings when the target wellbore is cleaned, and determine the numerical range of the particle Reynolds number.

[0046] Step B2: according to the numerical range of the particle Reynolds number, determine a target rock cuttings settling velocity calculation formula from a preset rock cuttings settling velocity calculation formula, and determine the target rock cuttings settling velocity.

[0047] Among them, the calculation formulas for the cuttings settling velocity are different for different numerical regions of the particle Reynolds number.

[0048] The particle Reynolds number Re for the settling flow p To judge, the Reynolds number of cuttings is calculated as:

[0049]

[0050] When Re p >2000 When the cuttings settling velocity is calculated, the formula is:

[0051]

[0052] When Re p When ≤1, the calculation formula for the rock cuttings settling velocity is:

[0053]

[0054] When 1<Re p When ≤2000, the calculation formula of cuttings settling velocity is:

[0055]

[0056]

[0057] In the formula, Re p is the particle Reynolds number; d s is the average diameter of rock debris particles, m; μ a is the apparent viscosity of the drilling fluid around the particles, mPa.s; ρ s is the density of rock cuttings, kg / m 3 ρ m is the drilling fluid density, kg / m 3 ;D hy is the hydraulic diameter of the annulus, m; n is the dimensionless exponent.

[0058] In the embodiment of the present invention, whether the drilling data meets the wellbore cleaning requirements is determined by the cuttings delivery ratio. If the cuttings delivery ratio is small, the cuttings cannot be removed from the wellbore in time, which will increase the wellbore cleaning time.

[0059] As an optional but non-limiting implementation, determining whether the drilling data meets the target wellbore cleaning requirement based on the drilling fluid annular return velocity vector sum and the cuttings settling velocity includes but is not limited to steps C1-C3:

[0060] Step C1: determining a cuttings transport ratio according to a vector sum of the drilling fluid annular return velocity and a cuttings settling velocity, and determining whether the cuttings transport ratio is greater than a preset cuttings transport ratio threshold.

[0061] Step C2: If the cuttings transport ratio is greater than a preset cuttings transport ratio threshold, it is determined that the drilling data meets the target wellbore cleaning requirement.

[0062] Step C3: If the cuttings transport ratio is not greater than a preset cuttings transport ratio threshold, the drilling fluid displacement and the drill string speed are modulated until the cuttings transport ratio is greater than the preset cuttings transport ratio threshold.

[0063] The calculation formula of cuttings transport ratio is:

[0064]

[0065] Wherein, R is the cuttings transport ratio. In the embodiment of the present invention, R=0.5 is used as the preset cuttings transport ratio threshold. When the cuttings transport ratio is greater than or equal to the preset cuttings transport ratio threshold, the drilling fluid displacement and drill string speed at this time meet the wellbore cleaning requirements. If the cuttings transport ratio is less than the preset cuttings transport ratio threshold, the drilling fluid displacement and drill string speed are readjusted until the cuttings transport ratio is greater than or equal to the preset cuttings transport ratio threshold, that is, the drilling fluid displacement and drill string speed are adjusted to meet the wellbore cleaning requirements.

[0066] In the embodiment of the present invention, the drilling fluid annular return velocity vector sum and the cuttings settling velocity are determined through drilling data, and the cuttings transport ratio is determined according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity; the cuttings transport ratio is used to determine whether the drilling time meets the wellbore cleaning requirement. By determining whether the drilling time meets the wellbore cleaning requirement, the drilling data is optimized and adjusted to reduce the wellbore cleaning time.

[0067] S130: When the drilling data meets the target wellbore cleaning requirement, determine the target wellbore cleaning cycle time under the condition of maximum annular cuttings concentration of the target wellbore according to the drilling data.

[0068] In the embodiment of the present invention, the maximum annular cuttings concentration is obtained under the maximum mechanical drilling speed condition, so as to determine the target cycle time for wellbore cleaning under the maximum annular cuttings concentration condition. If the target wellbore can be cleaned within the target cycle time under the maximum annular cuttings concentration condition, the target wellbore can be cleaned within the target cycle time under any annular cuttings concentration condition.

[0069] As an optional but non-limiting implementation, when the drilling data meets the target wellbore cleaning requirements, determining the target wellbore cleaning cycle time under the maximum annular cuttings concentration condition of the target wellbore according to the drilling data includes but is not limited to steps D1-D3:

[0070] Step D1: Determine the maximum mechanical rotation speed during target wellbore cleaning, and determine the maximum annular cuttings concentration under the maximum mechanical rotation speed condition.

[0071] Step D2: Determine the density of the annular liquid-solid mixed drilling fluid according to the drilling fluid density and the maximum annular cuttings concentration.

[0072] Step D3: Determine the target cycle time for cleaning the target wellbore under the condition of maximum annular cuttings concentration according to the density of the annular liquid-solid mixed drilling fluid and the drilling data.

[0073] Wherein, the maximum annular cuttings concentration is determined under the condition of maximum mechanical rotation speed, and the annular cuttings concentration calculation formula is:

[0074]

[0075] The density of the annular liquid-solid mixed drilling fluid is calculated based on the density of the drilling fluid and the density of the cuttings. The calculation formula for the density of the annular liquid-solid mixed drilling fluid is:

[0076] ρ min,max =ρ m ×(1-f max )+ρ s ×f max

[0077] Among them, ROP max is the maximum mechanical drilling speed, m / s; ρ min,max is the density of the annular liquid-solid mixed drilling fluid, kg / m 3 ;f max It is the maximum annular cuttings concentration under the condition of maximum mechanical speed.

[0078] As an optional but non-limiting implementation, the method of determining the target cycle time for cleaning the target wellbore under the condition of maximum annular cuttings concentration based on the density of the annular liquid-solid mixed drilling fluid and the drilling data includes but is not limited to steps E1-E3:

[0079] Step E1: Determine the measured bottom hole equivalent circulating density and pure drilling time.

[0080] Step E2: Determine the proportion of pure drilling time to column standing time based on the measured equivalent circulating density at the bottom of the hole and the density of the liquid-solid mixed drilling fluid in the annulus.

[0081] Step E3: determining the column cycle time according to the ratio of the pure drilling time to the column time and the pure drilling time, and determining the target wellbore cleaning cycle time according to the column cycle time.

[0082] Among them, the optimal circulation time for drilling the column under the condition of maximum cuttings concentration is calculated based on the measured bottom hole equivalent circulation density and pure drilling time. The calculation formula for the optimal circulation time for drilling the column under the condition of maximum annular cuttings concentration is:

[0083] ECD×X+ρ m ×(1-X)=ρ min,max

[0084]

[0085] The best cycle time after erecting the columns is:

[0086] t c =(1-X)×T

[0087] Among them, t c The best circulation time after column drilling, min; ECD is the measured equivalent circulating density at the bottom of the well, kg / m 3; T is the total column time (including pure drilling time and cycle time), min; X is the proportion of pure drilling time to column time.

[0088] In an optional solution of the embodiment of the present invention, the borehole cleaning cycle time is determined by determining the optimal cycle time for completing the column under the condition of maximum rock cuttings concentration. For example, the optimal cycle time for completing the column is determined after completing the column, thereby determining the target cycle time after completing the column; and the target borehole cleaning cycle time is determined based on the target cycle time.

[0089] The embodiment of the present invention provides a method for optimizing the cycle time of wellbore cleaning, by determining the drilling data when cleaning the target wellbore; the drilling data includes wellbore size, drilling fluid displacement, drilling fluid density and drill string rotation speed; according to the drilling data, the drilling fluid annular return velocity vector sum and the rock cuttings settling speed are determined, and according to the drilling fluid annular return velocity vector sum and the rock cuttings settling speed, it is determined whether the drilling data meets the target wellbore cleaning requirements; when the drilling data meets the target wellbore cleaning requirements, the target cycle time of wellbore cleaning under the condition of maximum annular rock cuttings concentration is determined according to the drilling data. The technical solution of the embodiment of the present invention is adopted, and under the condition that the annular pressure measurement data can be obtained while drilling, the drilling fluid displacement, drill string rotation speed and column completion cycle time during the drilling process are optimized and analyzed, so as to save the wellbore cleaning time under the premise of ensuring drilling safety.

[0090] Figure 2 The flowchart of a method for optimizing the cycle time of a wellbore cleaning provided in an embodiment of the present invention is shown in FIG. The embodiment of the present invention further optimizes the above embodiment on the basis of the above embodiment, and the embodiment of the present invention can be combined with various optional solutions in one or more of the above embodiments. Figure 2 As shown, the wellbore cleaning cycle time optimization method provided in the embodiment of the present invention may include the following steps:

[0091] S210, determining the axial flow velocity of the drilling fluid according to the drilling fluid displacement, determining the circumferential flow velocity of the drilling fluid according to the drill string rotation speed, and superimposing the axial flow velocity of the drilling fluid and the circumferential flow velocity of the drilling fluid to determine the vector sum of the drilling fluid annulus return velocity.

[0092] In the embodiment of the present invention, an actual well is taken as an example. The borehole size of Well A is 311.2 mm, the outer diameter of the drill string is 139.7 mm, the drilling fluid displacement is 60 L / s, and the drilling fluid density is 1.5 g / cm 3 , rock cuttings density 2.2g / cm 3 , n = 0.65, k = 0.40Pa.s, drill string speed 80RPM. The axial velocity of the drilling fluid determined by the drilling fluid displacement is:

[0093]

[0094] The circumferential flow rate of drilling fluid determined by the drill string rotation speed is:

[0095]

[0096] The drilling fluid axial velocity and the drilling fluid circumferential velocity are vector-superimposed to determine the drilling fluid annular return velocity vector sum:

[0097]

[0098] S220. Calculate the rock cuttings settling velocity according to the drilling fluid parameters and the rock cuttings particle parameters.

[0099] After determining the particle Reynolds number of the cuttings, determine the numerical range of the particle Reynolds number, thereby determining the target cuttings settling velocity calculation formula and determining the target cuttings settling velocity. Among them, the apparent viscosity of the drilling fluid around the particles is:

[0100]

[0101] Assume that the Reynolds number of medium particles is 1<Re p ≤2000, the rock cuttings settling velocity is calculated as:

[0102]

[0103] S230, determining the cuttings transport ratio according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity.

[0104]

[0105] In the embodiment of the present invention, the preset cuttings transport ratio threshold is 0.5. If the current cuttings transport ratio is greater than 0.5, the drilling fluid displacement of 60 L / s and the drill string speed of 80 RMP meet the wellbore cleaning requirements.

[0106] In an optional solution of an embodiment of the present invention, if it is determined that the cuttings conveying ratio is less than a preset cuttings conveying ratio threshold, the drilling fluid displacement and the drill string speed are adjusted until the cuttings conveying ratio is greater than or equal to the preset cuttings conveying ratio threshold.

[0107] S240. Calculate the maximum annular cuttings concentration based on the maximum mechanical drilling speed, and calculate the annular liquid-solid mixed drilling fluid density based on the drilling fluid density and the cuttings density.

[0108] Assuming that the maximum mechanical drilling speed is 120m / h, the calculation formula for the annular cuttings concentration under the condition of maximum mechanical drilling speed is:

[0109]

[0110] The density of the annular liquid-solid mixed drilling fluid calculated based on the drilling fluid density and the cuttings density is:

[0111] ρ min,max =1.5×0.95+2.2×0.05=1.535g / cm 3

[0112] S250. Calculate the optimal circulation time to complete column drilling under the condition of maximum cuttings concentration based on the measured bottom hole equivalent circulation density and pure drilling time.

[0113] Assume that the measured bottom hole equivalent circulating density is 1.585 g / cm 3 , the proportion of pure drilling time to column erection time:

[0114]

[0115] Assuming that the total time for column drilling is 100 minutes, the pure drilling time is 41 minutes, and the optimal cycle time for completing the column drilling is 59 minutes.

[0116] The embodiment of the present invention provides a method for optimizing the cycle time of borehole cleaning. The axial flow velocity of the drilling fluid is determined according to the drilling fluid displacement, the circumferential flow velocity of the drilling fluid is determined according to the drill string rotation speed, the axial flow velocity of the drilling fluid and the circumferential flow velocity of the drilling fluid are vector-superimposed to determine the vector sum of the annular return velocity of the drilling fluid; the cuttings settling velocity is calculated according to the drilling fluid parameters and the cuttings particle parameters; the cuttings transport ratio is determined according to the vector sum of the annular return velocity of the drilling fluid and the cuttings settling velocity; the maximum annular cuttings concentration is calculated according to the maximum mechanical drilling speed, and the annular liquid-solid mixed drilling fluid density is calculated according to the drilling fluid density and the cuttings density; the optimal cycle time for completing the column under the condition of maximum cuttings concentration is calculated according to the measured bottom hole equivalent circulation density and the pure drilling time. The technical solution of the embodiment of the present invention is adopted to determine whether the current drilling fluid displacement and the drill string rotation speed meet the borehole cleaning requirements; if the borehole cleaning requirements are not met, the current drilling fluid displacement and the drill string rotation speed are optimized and adjusted. After the borehole leave requirements are met, the column cycle time is determined to determine the borehole cleaning time. The solution method for optimizing the cycle time of cleaning wellbore proposed in this scheme can provide quantitative calculation and analysis for wellbore cleaning construction parameters and processes, and in the future it can provide simulation calculation technology support for automated drilling safety monitoring.

[0117] Figure 3 : is a schematic diagram of the structure of a borehole cleaning cycle time optimization device provided in an embodiment of the present invention. The technical solution of this embodiment can be applied to the situation of optimizing the borehole cleaning cycle time. The device can be implemented by software and / or hardware and is generally integrated on any electronic device with network communication function, including but not limited to: servers, computers, personal digital assistants and other devices. Figure 3As shown, the wellbore cleaning cycle time optimization device provided in this embodiment may include: a drilling data determination module 310, a cleaning demand determination module 320 and a cycle time determination module 330; wherein,

[0118] The drilling data determination module 310 is used to determine the drilling data when the target wellbore is cleaned; the drilling data includes wellbore size, drilling fluid displacement, drilling fluid density and drill string rotation speed;

[0119] A cleaning requirement determination module 320 is used to determine the drilling fluid annular return velocity vector sum and the cuttings settling velocity according to the drilling data, and determine whether the drilling data meets the target wellbore cleaning requirement according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity;

[0120] The cycle time determination module 330 is used to determine the target cycle time for cleaning the target wellbore under the condition of maximum annular cuttings concentration according to the drilling data when the drilling data meets the target wellbore cleaning requirement.

[0121] Based on the above embodiment, optionally, the cleaning requirement determination module is specifically used to:

[0122] Determine the axial flow velocity of the drilling fluid based on the drilling fluid displacement;

[0123] Determine the circumferential flow rate of the drilling fluid based on the drill string rotation speed;

[0124] The drilling fluid axial flow velocity and the drilling fluid circumferential flow velocity are vector-superimposed to determine the drilling fluid annular return velocity vector sum.

[0125] Based on the above embodiment, optionally, the cleaning requirement determination module is further specifically used for:

[0126] Determine the particle Reynolds number of the rock cuttings when the target wellbore is cleaned, and determine the numerical range of the particle Reynolds number;

[0127] According to the numerical range of the particle Reynolds number, a target rock cuttings settling velocity calculation formula is determined from a preset rock cuttings settling velocity calculation formula, and a target rock cuttings settling velocity is determined;

[0128] Among them, the calculation formulas for the cuttings settling velocity are different for different numerical regions of the particle Reynolds number.

[0129] Based on the above embodiment, optionally, the cleaning requirement determination module is further specifically used for:

[0130] Determine a cuttings transport ratio according to a vector sum of the drilling fluid annular return velocity and a cuttings settling velocity, and determine whether the cuttings transport ratio is greater than a preset cuttings transport ratio threshold;

[0131] If the cuttings transport ratio is greater than a preset cuttings transport ratio threshold, determining that the drilling data meets the target wellbore cleaning requirement;

[0132] If the cuttings transport ratio is not greater than the preset cuttings transport ratio threshold, the drilling fluid displacement and the drill string speed are modulated until the cuttings transport ratio is greater than the preset cuttings transport ratio threshold.

[0133] Based on the above embodiment, optionally, the cycle time determination module is specifically used to:

[0134] Determine the maximum mechanical speed for target wellbore cleaning and determine the maximum annular cuttings concentration under the condition of maximum mechanical speed;

[0135] Determine the density of the annular liquid-solid mixed drilling fluid based on the drilling fluid density and the maximum annular cuttings concentration;

[0136] The target circulation time for wellbore cleaning under the condition of maximum annular cuttings concentration is determined based on the density of the annular liquid-solid mixed drilling fluid and drilling data.

[0137] Based on the above embodiment, optionally, the cycle time determination module is further specifically used for:

[0138] Determine the measured bottom hole equivalent circulating density and pure drilling time;

[0139] Determine the proportion of pure drilling time to column time based on the measured equivalent circulating density at the bottom of the hole and the density of the liquid-solid mixed drilling fluid in the annulus;

[0140] The column cycle time is determined according to the ratio of the pure drilling time to the column time and the pure drilling time, and the target wellbore cleaning cycle time is determined according to the column cycle time.

[0141] The wellbore cleaning cycle time optimization device provided in the embodiments of the present invention can execute the wellbore cleaning cycle time optimization method provided in any of the above embodiments of the present invention, and has the corresponding functions and beneficial effects of executing the wellbore cleaning cycle time optimization method. For detailed processes, please refer to the relevant operations of the wellbore cleaning cycle time optimization method in the above embodiments.

[0142] Figure 41 is a schematic diagram of the structure of an electronic device provided in an embodiment of the present invention. The electronic device 10 is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device may also represent various forms of mobile devices, such as personal digital processing, cellular phones, smart phones, wearable devices (such as helmets, glasses, watches, etc.) and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely examples and are not intended to limit the implementation of the present invention described and / or required herein.

[0143] like Figure 4 As shown, the electronic device 10 includes at least one processor 11, and a memory connected to the at least one processor 11, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., wherein the memory stores a computer program that can be executed by at least one processor, and the processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or the computer program loaded from the storage unit 18 to the random access memory (RAM) 13. In the RAM 13, various programs and data required for the operation of the electronic device 10 can also be stored. The processor 11, the ROM 12, and the RAM 13 are connected to each other through a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0144] A number of components in the electronic device 10 are connected to the I / O interface 15, including: an input unit 16, such as a keyboard, a mouse, etc.; an output unit 17, such as various types of displays, speakers, etc.; a storage unit 18, such as a disk, an optical disk, etc.; and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices through a computer network such as the Internet and / or various telecommunication networks.

[0145] The processor 11 may be a variety of general and / or special processing components with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various dedicated artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any appropriate processor, controller, microcontroller, etc. The processor 11 executes the various methods and processes described above, such as a wellbore cleaning cycle time optimization method.

[0146] In some embodiments, the borehole cleaning cycle time optimization method may be implemented as a computer program, which is tangibly contained in a computer-readable storage medium, such as a storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or installed on the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the borehole cleaning cycle time optimization method described above may be performed. Alternatively, in other embodiments, the processor 11 may be configured to perform the borehole cleaning cycle time optimization method in any other suitable manner (e.g., by means of firmware).

[0147] Various implementations of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), systems on chips (SOCs), load programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various implementations can include: being implemented in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which can be a special purpose or general purpose programmable processor that can receive data and instructions from a storage system, at least one input device, and at least one output device, and transmit data and instructions to the storage system, the at least one input device, and the at least one output device.

[0148] Computer programs for implementing the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, so that when the computer program is executed by the processor, the functions / operations specified in the flow chart and / or block diagram are implemented. The computer program may be executed entirely on the machine, partially on the machine, partially on the machine and partially on a remote machine as a stand-alone software package, or entirely on a remote machine or server.

[0149] In the context of the present invention, a computer-readable storage medium may be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, device, or equipment. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, devices, or equipment, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. A more specific example of a machine-readable storage medium may include an electrical connection based on one or more lines, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing.

[0150] To provide interaction with a user, the systems and techniques described herein may be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and a pointing device (e.g., a mouse or trackball) through which the user can provide input to the electronic device. Other types of devices may also be used to provide interaction with the user; for example, the feedback provided to the user may be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user may be received in any form (including acoustic input, voice input, or tactile input).

[0151] The systems and techniques described herein may be implemented in a computing system that includes backend components (e.g., as a data server), or a computing system that includes middleware components (e.g., an application server), or a computing system that includes frontend components (e.g., a user computer with a graphical user interface or a web browser through which a user can interact with implementations of the systems and techniques described herein), or a computing system that includes any combination of such backend components, middleware components, or frontend components. The components of the system may be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include: a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0152] A computing system may include a client and a server. The client and the server are generally remote from each other and usually interact through a communication network. The client and server relationship is generated by computer programs running on the corresponding computers and having a client-server relationship with each other. The server may be a cloud server, also known as a cloud computing server or cloud host, which is a host product in the cloud computing service system to solve the defects of difficult management and weak business scalability in traditional physical hosts and VPS services.

[0153] It should be understood that the various forms of processes shown above can be used to reorder, add or delete steps. For example, the steps described in the present invention can be executed in parallel, sequentially or in different orders, as long as the desired results of the technical solution of the present invention can be achieved, and this document does not limit this.

[0154] The above specific implementations do not constitute a limitation on the protection scope of the present invention. It should be understood by those skilled in the art that various modifications, combinations, sub-combinations and substitutions can be made according to design requirements and other factors. Any modification, equivalent substitution and improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims

1. A method for optimizing the cycle time of wellbore cleaning, characterized in that: The method comprises: Determine the drilling data when the target wellbore is cleaned; the drilling data includes wellbore size, drilling fluid displacement, drilling fluid density and drill string rotation speed; Determine the drilling fluid annular return velocity vector sum and the cuttings settling velocity according to the drilling data, and determine whether the drilling data meets the target wellbore cleaning requirements according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity; When the drilling data meets the target wellbore cleaning requirement, a target wellbore cleaning cycle time of the target wellbore under the condition of maximum annular cuttings concentration is determined according to the drilling data.

2. The method according to claim 1, characterized in that Determining the drilling fluid annular return velocity vector sum according to the drilling data includes: Determine the axial flow velocity of the drilling fluid based on the drilling fluid displacement; Determine the circumferential flow rate of the drilling fluid based on the drill string rotation speed; The drilling fluid axial flow velocity and the drilling fluid circumferential flow velocity are vector-superimposed to determine the drilling fluid annular return velocity vector sum.

3. The method according to claim 1, characterized in that Determining the rock cuttings settling velocity according to the drilling data comprises: Determine the particle Reynolds number of the rock cuttings when the target wellbore is cleaned, and determine the numerical range of the particle Reynolds number; According to the numerical range of the particle Reynolds number, a target rock cuttings settling velocity calculation formula is determined from a preset rock cuttings settling velocity calculation formula, and a target rock cuttings settling velocity is determined; Among them, the calculation formulas for the cuttings settling velocity are different for different numerical regions of the particle Reynolds number.

4. The method according to claim 1, characterized in that: Determining whether the drilling data meets the target wellbore cleaning requirement based on the drilling fluid annular return velocity vector sum and the cuttings settling velocity includes: Determine a cuttings transport ratio according to a vector sum of the drilling fluid annular return velocity and a cuttings settling velocity, and determine whether the cuttings transport ratio is greater than a preset cuttings transport ratio threshold; If the cuttings transport ratio is greater than a preset cuttings transport ratio threshold, determining that the drilling data meets the target wellbore cleaning requirement; If the cuttings transport ratio is not greater than the preset cuttings transport ratio threshold, the drilling fluid displacement and the drill string speed are modulated until the cuttings transport ratio is greater than the preset cuttings transport ratio threshold.

5. The method according to claim 1, characterized in that When the drilling data meets the target wellbore cleaning requirement, determining the target wellbore cleaning cycle time of the target wellbore under the condition of maximum annular cuttings concentration according to the drilling data includes: Determine the maximum mechanical speed for target wellbore cleaning and determine the maximum annular cuttings concentration under the condition of maximum mechanical speed; Determine the density of the annular liquid-solid mixed drilling fluid based on the drilling fluid density and the maximum annular cuttings concentration; The target circulation time for wellbore cleaning under the condition of maximum annular cuttings concentration is determined based on the density of the annular liquid-solid mixed drilling fluid and drilling data.

6. The method according to claim 5, characterized in that The method of determining the target cycle time for cleaning the target wellbore under the condition of maximum annular cuttings concentration based on the density of the annular liquid-solid mixed drilling fluid and the drilling data includes: Determine the measured bottom hole equivalent circulating density and pure drilling time; Determine the proportion of pure drilling time to column time based on the measured equivalent circulating density at the bottom of the hole and the density of the liquid-solid mixed drilling fluid in the annulus; The column cycle time is determined according to the ratio of the pure drilling time to the column time and the pure drilling time, and the target wellbore cleaning cycle time is determined according to the column cycle time.

7. A wellbore cleaning cycle time optimization device, characterized in that: The device comprises: A drilling data determination module is used to determine the drilling data when the target wellbore is cleaned; the drilling data includes wellbore size, drilling fluid displacement, drilling fluid density and drill string rotation speed; A cleaning requirement determination module, used to determine the drilling fluid annular return velocity vector sum and the cuttings settling velocity according to the drilling data, and determine whether the drilling data meets the target wellbore cleaning requirement according to the drilling fluid annular return velocity vector sum and the cuttings settling velocity; The cycle time determination module is used to determine the target cycle time of the target wellbore cleaning under the condition of maximum annular cuttings concentration according to the drilling data when the drilling data meets the target wellbore cleaning requirements.

8. The device according to claim 7, characterized in that The cleaning requirement determination module is specifically used for: Determine the axial flow velocity of the drilling fluid based on the drilling fluid displacement; Determine the circumferential flow rate of the drilling fluid based on the drill string rotation speed; The drilling fluid axial flow velocity and the drilling fluid circumferential flow velocity are vector-superimposed to determine the drilling fluid annular return velocity vector sum.

9. An electronic device, characterized in that: include: one or more processors; A storage device for storing one or more programs; When the one or more programs are executed by the one or more processors, the one or more processors implement the wellbore cleaning cycle time optimization method according to any one of claims 1 to 6.

10. A storage medium containing computer executable instructions, characterized in that: The computer executable instructions are used to perform the wellbore cleaning cycle time optimization method as described in any one of claims 1-6 when executed by a computer processor.

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