A wellbore cleaning cycle time optimization method and device, electronic equipment and medium

Abstract

Embodiments of the present application disclose a wellbore cleaning circulation time optimization method, device, electronic equipment and medium. The method comprises: determining drilling data at a target wellbore cleaning time; the drilling data comprises wellbore size, drilling fluid discharge, drilling fluid density and drill string rotation speed; determining drilling fluid annular return speed vector sum and cuttings settling velocity according to the drilling data, and determining whether the drilling data meets target wellbore cleaning requirements according to the drilling fluid annular return speed vector sum and the cuttings settling velocity; when the drilling data meets the target wellbore cleaning requirements, determining a wellbore cleaning target circulation time of the target wellbore under a maximum annular cuttings concentration condition according to the drilling data. The technical solution of the embodiments of the present application can realize optimization analysis of drilling fluid discharge, drill string rotation speed and stand-by-pipe circulation time in the drilling process under the condition that drilling annular pressure measurement data can be obtained, and saves wellbore cleaning time under the premise of ensuring drilling safety.

Description

Technical Field

[0001] This invention relates to the field of oil and gas drilling safety monitoring technology, and in particular to a method, apparatus, electronic device and medium for optimizing wellbore cleaning cycle time. Background Technology

[0002] Poor wellbore cleaning during oil and gas drilling can lead to high friction and torque, prolonged circulation, and frequent reaming, potentially resulting in complex accidents such as stuck pipe and sidetracking. Therefore, employing appropriate drilling parameters and construction procedures to facilitate the timely return of formation cuttings to the wellbore is crucial for improving drilling speed, shortening drilling cycles, and ensuring drilling safety.

[0003] With the development of downhole parameter measurement technology, monitoring wellbore cleanliness using downhole annular pressure measurement data has become increasingly common. However, existing wellbore cleanliness evaluation methods based on downhole annular pressure still have certain problems, such as: using theoretical techniques for annular pressure parameters instead of actual measured data, which affects the accuracy of calculation results; not optimizing wellbore cleanliness parameters; and not optimizing wellbore cleanliness cycle time. Summary of the Invention

[0004] This invention provides a method, apparatus, electronic device, and storage medium for optimizing wellbore cleaning cycle time, so as to achieve optimization analysis of displacement, rotation speed, and cycle time after drilling the standpipe during the drilling process, thereby saving drilling time while ensuring drilling safety.

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

[0006] Determine the drilling data during target wellbore cleaning; the drilling data includes wellbore size, drilling fluid flow rate, drilling fluid density, and drill string rotation speed;

[0007] Based on the drilling data, determine the resultant vector of drilling fluid annular return velocity and the cuttings settling velocity, and determine whether the drilling data meets the target wellbore cleaning requirements based on the resultant vector of drilling fluid annular return velocity and the cuttings settling velocity.

[0008] When the drilling data meets the target wellbore cleaning requirements, the target wellbore cleaning cycle time under the maximum annular cuttings concentration condition is determined based on the drilling data.

[0009] Secondly, embodiments of the present invention also provide a wellbore cleaning cycle time optimization device, comprising:

[0010] The drilling data determination module is used to determine the drilling data during target wellbore cleaning; the drilling data includes wellbore size, drilling fluid flow rate, drilling fluid density, and drill string rotation speed;

[0011] The cleaning requirement determination module is used to determine the drilling fluid annular return velocity vector sum and cuttings settling velocity based on the drilling data, and to determine whether the drilling data meets the target wellbore cleaning requirements based on the drilling fluid annular return velocity vector sum and cuttings settling velocity.

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

[0013] Thirdly, embodiments of the present invention also provide an electronic device, the electronic device comprising:

[0014] One or more processors;

[0015] 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 according to any embodiment of the present invention.

[0017] Fourthly, embodiments of the present invention also provide 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] This invention provides a method, apparatus, electronic device, and storage medium for optimizing wellbore cleaning cycle time. The method involves determining drilling data for target wellbore cleaning, including wellbore size, drilling fluid flow rate, drilling fluid density, and drill string rotation speed. Based on this data, the method determines the combined annular return velocity vector and cuttings settling velocity, and then determines whether the drilling data meets the target wellbore cleaning requirements. If the drilling data meets the target wellbore cleaning requirements, the method determines the target wellbore cleaning cycle time under the condition of maximum annular cuttings concentration. By employing the technical solution of this invention, and with the availability of annular pressure measurement data during drilling, the method achieves optimized analysis of drilling fluid flow rate, drill string rotation speed, and cycle time after drill string installation, saving wellbore cleaning time while ensuring drilling safety. Attached Figure Description

[0019] Other features, objects, and advantages of the invention will become more apparent from the following detailed description of non-limiting embodiments with reference to the accompanying drawings. The drawings are for illustrative purposes only and are not intended to limit the invention. Furthermore, the same reference numerals denote the same parts throughout the drawings. In the drawings:

[0020] Figure 1 This is a flowchart of a wellbore cleaning cycle time optimization method provided in an embodiment of the present invention;

[0021] Figure 2 This is a flowchart of another wellbore cleaning cycle time optimization method provided in an embodiment of the present invention;

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

[0023] Figure 4 This is a schematic diagram of the structure of an electronic device provided in an embodiment of the present invention. Detailed Implementation

[0024] The present invention will now be described in further detail with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the invention and not intended to limit it. Furthermore, it should be noted that, for ease of description, the accompanying drawings show only the parts relevant to the present invention, and not all of the structures.

[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 flowcharts. Although the flowcharts describe the operations (or steps) as sequential processes, many of the operations (or steps) may be performed in parallel, concurrently, or simultaneously. Furthermore, the order of the operations may be rearranged. The process may be terminated when its operation is completed, but may also have additional steps not included in the figures. The process may correspond to a method, function, procedure, subroutine, subroutine, etc.

[0026] The acquisition, storage, use, and processing of data in the technical solution of this application all comply with the relevant provisions of national laws and regulations.

[0027] Figure 1 This is a flowchart illustrating a method for optimizing wellbore cleaning cycle time according to an embodiment of the present invention. This embodiment is applicable to situations requiring optimization of wellbore cleaning cycle time. The method in this embodiment can be executed by a wellbore cleaning cycle time optimization device, which can be implemented using hardware and / or software. This device can be configured in a server for wellbore cleaning cycle time optimization. The method specifically includes the following steps:

[0028] S110. Determine the drilling data during target wellbore cleaning.

[0029] When determining the wellbore cleaning cycle time, drilling data for wellbore cleaning must first be obtained. This drilling data includes, but is not limited to, wellbore size, drilling fluid flow rate, drilling fluid density, and drill string rotation speed. Different drilling data values ​​will affect the cycle time during wellbore cleaning; for example, a smaller drilling fluid flow rate will result in a shorter wellbore cleaning time. However, for loose formations, the drilling fluid flow rate should not be too large to avoid eroding the wellbore and causing wellbore instability. In this embodiment of the invention, the drilling data is optimized to improve the wellbore cleaning cycle time while ensuring drilling safety and successful wellbore cleaning.

[0030] S120. Based on the drilling data, determine the drilling fluid annular return velocity vector sum and the cuttings settling velocity, and determine whether the drilling data meets the target wellbore cleaning requirements based on the drilling fluid annular return velocity vector sum and the cuttings settling velocity.

[0031] The higher the annular return velocity of the drilling fluid, the easier it is for cuttings to rise, and the less likely a cuttings bed will form in the wellbore. However, if the annular return velocity is too high, it will erode the wellbore, causing it to collapse, and will also result in mixed cuttings, affecting the quality of cuttings logging. In this embodiment of the invention, the vector sum of the annular return velocity of the drilling fluid is obtained by vector superposition of the axial flow velocity and the circumferential flow velocity of the drilling fluid.

[0032] As an optional but non-limiting implementation, determining the drilling fluid annular return velocity vector 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 based on the drilling fluid discharge rate.

[0034] Step A2: Determine the circumferential flow velocity of the drilling fluid based on the drill string rotation speed.

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

[0036] The drilling fluid axial velocity is calculated based on the drilling fluid displacement. The formula for calculating the drilling fluid axial velocity along the drill string is as follows:

[0037]

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

[0039]

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

[0041]

[0042] Among them, V a The axial velocity of the drilling fluid is represented by m / s; Q is the drilling fluid displacement, m³ / s. 3 / s;D h D is the wellbore diameter, in meters. p V is the drill string diameter, in meters. tp Characterized by the circumferential velocity of the drilling fluid, m / s; RPM is the drill string rotation speed, rev / min; eff is the efficiency coefficient of drilling fluid flow driven by drill string rotation, typically taken as 0.25; V at The vector sum of the annular return velocity of drilling fluid, in m / s.

[0043] Rock cuttings settling velocity refers to the settling velocity of rock cuttings relative to the mud under the influence of natural gravity. Rock cuttings settling velocity is related not only to the fluid flow regime but also to the particle settling flow regime. When rock cuttings settle, the downstream wake streamlines move smoothly without generating flow around them, resulting in laminar flow; conversely, it is plain flow. There is a transitional settling flow regime range between laminar and plain flow.

[0044] As an optional but non-limiting implementation, determining 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 cuttings during target wellbore cleaning, and determine the numerical range of the particle Reynolds number.

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

[0047] The formula for calculating the settling velocity of rock debris varies depending on the numerical range of the particle Reynolds number.

[0048] Sedimentation flow regime using particle Reynolds number Re p To determine this, the formula for calculating the Reynolds number of rock cuttings is:

[0049]

[0050] When Re p The formula for calculating the settling velocity of rock cuttings at >2000 is:

[0051]

[0052] When Re p The formula for calculating the settling velocity of rock cuttings when ≤1 is:

[0053]

[0054] When 1<Re p The formula for calculating the settling velocity of rock cuttings when the density is ≤2000 is:

[0055]

[0056]

[0057] In the formula, Re p d is the particle Reynolds number; s The average diameter of the rock fragments is in meters (m); μ a The apparent viscosity of the drilling fluid surrounding the particles is given in mPa·s; ρ s Density of rock fragments, kg / m³ 3 ;ρ m Density of drilling fluid, kg / m³ 3 ;D hy denoted as the annular hydraulic diameter, in meters (m); n is a dimensionless exponent.

[0058] In this embodiment of the invention, the drilling data is determined to meet the wellbore cleaning requirements 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 requirements based on the combined annular return velocity vector of the drilling fluid and the cuttings settling velocity includes, but is not limited to, steps C1-C3:

[0060] Step C1: Determine the cuttings delivery ratio based on the combined annular return velocity vector of the drilling fluid and the cuttings settling velocity, and determine whether the cuttings delivery ratio is greater than a preset cuttings delivery ratio threshold.

[0061] Step C2: If the cuttings delivery ratio is greater than the preset cuttings delivery ratio threshold, then the drilling data is determined to meet the target wellbore cleaning requirements.

[0062] Step C3: If the cuttings delivery ratio is not greater than the preset cuttings delivery ratio threshold, the drilling fluid discharge rate and drill string speed are adjusted until the cuttings delivery ratio is greater than the preset cuttings delivery ratio threshold.

[0063] The formula for calculating the cuttings transport ratio is as follows:

[0064]

[0065] Where R represents the cuttings delivery ratio, in this embodiment of the invention, R = 0.5 is used as the preset cuttings delivery ratio threshold. When the cuttings delivery ratio is greater than or equal to the preset cuttings delivery ratio threshold, the drilling fluid discharge rate and drill string speed meet the wellbore cleanliness requirements. If the cuttings delivery ratio is less than the preset cuttings delivery ratio threshold, the drilling fluid discharge rate and drill string speed are readjusted until the cuttings delivery ratio is greater than or equal to the preset cuttings delivery ratio threshold, that is, the drilling fluid discharge rate and drill string speed are adjusted to meet the wellbore cleanliness requirements.

[0066] In this embodiment of the invention, the drilling fluid annular return velocity vector sum and cuttings settling velocity are determined using drilling data, and the cuttings delivery ratio is determined based on these parameters. The cuttings delivery ratio is then used to determine whether the drilling time meets the wellbore cleaning requirements. By determining whether the drilling time meets the wellbore cleaning requirements, the drilling data is optimized and adjusted to reduce the wellbore cleaning time.

[0067] S130. When the drilling data meets the target wellbore cleaning requirements, determine the target wellbore cleaning target cycle time under the maximum annular cuttings concentration condition based on the drilling data.

[0068] In this embodiment of the invention, the maximum annular cuttings concentration is obtained under the maximum mechanical drilling rate, thereby determining the target circulation time for wellbore cleaning under the maximum annular cuttings concentration condition. If the target wellbore can be cleaned within the target circulation time under the maximum annular cuttings concentration condition, then the target wellbore can be cleaned within the target circulation 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, the target wellbore cleaning target circulation time under the condition of maximum annular cuttings concentration is determined based on the drilling data, including but 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 fluid-solid mixture drilling fluid based on the drilling fluid density and the maximum annular cuttings concentration.

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

[0073] The maximum annular rock fragment concentration is determined under the condition of maximum mechanical rotation speed, and the formula for calculating the annular rock fragment concentration is as follows:

[0074]

[0075] The density of the annular fluid-solid mixture is calculated based on the drilling fluid density and cuttings density. The formula for calculating the density of the annular fluid-solid mixture is as follows:

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

[0077] Among them, ROP max The maximum mechanical drilling rate is given in m / s; ρ min,max Density of the annular liquid-solid mixed drilling fluid, kg / m³ 3 ;f max This represents the maximum annular rock debris concentration under the condition of maximum mechanical rotation speed.

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

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

[0080] Step E2: Determine the proportion of pure drilling time to stand-up time based on the measured bottom hole equivalent circulation density and the density of the annular fluid-solid mixture.

[0081] Step E3: Determine the standpipe circulation time based on the ratio of pure drilling time to standpipe time and the pure drilling time, and determine the target wellbore cleaning circulation time based on the standpipe circulation time.

[0082] The optimal circulation time for completing the drill string under maximum cuttings concentration conditions was calculated based on the measured bottom-hole equivalent circulation density and pure drilling time. The formula for calculating the optimal circulation time for completing the drill string under maximum annular cuttings concentration is as follows:

[0083] ECD×X+ρ m ×(1-X)=ρ min,max

[0084]

[0085] The optimal cycle time to complete the pillar construction is:

[0086] t c = (1-X)×T

[0087] Among them, t c Optimal circulation time after drilling the support column, in minutes; ECD is the measured bottom-hole equivalent circulation density, in kg / m³. 3T represents the total standby time (including pure drilling time and circulation time), in min; X represents the proportion of pure drilling time to standby time.

[0088] In one optional embodiment of the present invention, the wellbore cleaning cycle time is determined by determining the optimal circulation time for completing the drill string under the condition of maximum cuttings concentration. For example, the optimal circulation time for completing one drill string is determined after completing one drill string, thereby determining the target circulation time after completing several drill strings; the target wellbore cleaning cycle time is then determined based on the target circulation time.

[0089] This invention provides a method for optimizing wellbore cleaning cycle time. The method involves determining drilling data for the target wellbore cleaning process. This data includes wellbore size, drilling fluid flow rate, drilling fluid density, and drill string rotation speed. Based on this data, the method determines the combined annular return velocity vector and cuttings settling velocity, and then determines whether the drilling data meets the target wellbore cleaning requirements. If the drilling data meets the target wellbore cleaning requirements, the method determines the target wellbore cleaning cycle time under the condition of maximum annular cuttings concentration. By employing the technical solution of this invention, and with the availability of annular pressure measurement data during drilling, the method optimizes the drilling fluid flow rate, drill string rotation speed, and cycle time after drilling, ensuring drilling safety while saving wellbore cleaning time.

[0090] Figure 2 This is a flowchart illustrating a method for optimizing wellbore cleaning cycle time according to an embodiment of the present invention. The embodiments of the present invention further optimize the aforementioned embodiments, and can be combined with various optional solutions from one or more of the above embodiments. For example... Figure 2 As shown, the wellbore cleaning cycle time optimization method provided in this embodiment of the invention may include the following steps:

[0091] S210. Determine the axial velocity of the drilling fluid based on the drilling fluid discharge rate, and determine the circumferential velocity of the drilling fluid based on the drill string rotation speed. Vector superimpose the axial velocity and circumferential velocity of the drilling fluid to determine the vector sum of the annular return velocity of the drilling fluid.

[0092] In this embodiment of the invention, an actual well (Well A) is used as an example. The wellbore size is 311.2 mm, the drill string outer diameter is 139.7 mm, the drilling fluid flow rate is 60 L / s, and the drilling fluid density is 1.5 g / cm³. 3 Rock cutting density 2.2 g / cm³ 3 Given n = 0.65, k = 0.40 Pa·s, and drill string speed of 80 RPM, the axial flow velocity of the drilling fluid, determined based on the drilling fluid displacement, is:

[0093]

[0094] The circumferential flow velocity of the drilling fluid, determined based on the drill string rotation speed, is:

[0095]

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

[0097]

[0098] S220. Calculate the cuttings settling velocity based on drilling fluid parameters and cuttings particle parameters.

[0099] After determining the particle Reynolds number of the cuttings, the numerical range of that particle Reynolds number is determined, thereby establishing the formula for calculating the target cuttings settling velocity and determining the target cuttings settling velocity. The apparent viscosity of the drilling fluid surrounding the particles is:

[0100]

[0101] Assuming medium-sized particles, the Reynolds number 1 < Re p If the value is ≤2000, then the rock cuttings settling velocity is calculated as follows:

[0102]

[0103] S230. The cuttings delivery ratio is determined based on the combined annular return velocity vector of the drilling fluid and the cuttings settling velocity.

[0104]

[0105] In this embodiment of the invention, the preset cuttings delivery ratio threshold is 0.5. If the current cuttings delivery ratio is greater than 0.5, then the drilling fluid discharge rate of 60L / s and the drill string rotation speed of 80RPM meet the wellbore cleanliness requirements.

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

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

[0108] Assuming a maximum mechanical drilling rate of 120 m / h, the formula for calculating the annular cuttings concentration under the condition of maximum mechanical drilling rate is:

[0109]

[0110] The density of the annular liquid-solid mixed drilling fluid, calculated based on the drilling fluid density and 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 the drilling of the support column under the condition of maximum cuttings concentration based on the measured equivalent circulation density at the bottom of the well and the pure drilling time.

[0113] Assume the measured equivalent circulating density at the bottom of the well is 1.585 g / cm³. 3 The percentage of pure drilling time to column erection time:

[0114]

[0115] Assuming a total drilling time of 100 minutes, the pure drilling time is 41 minutes, and the optimal cycle time to complete drilling the column is 59 minutes.

[0116] This invention provides an optimization method for wellbore cleaning circulation time. The method involves determining the axial flow velocity of the drilling fluid based on the drilling fluid discharge rate and the circumferential flow velocity based on the drill string rotation speed. The axial and circumferential flow velocities are vector-superimposed to determine the annular return velocity vector sum. The cuttings settling velocity is calculated based on drilling fluid and cuttings particle parameters. The cuttings delivery ratio is determined based on the annular return velocity vector sum and the cuttings settling velocity. The maximum annular cuttings concentration is calculated based on the maximum mechanical drilling rate, and the annular liquid-solid mixed drilling fluid density is calculated based on the drilling fluid density and cuttings density. The optimal circulation time for completing the standpipe operation under the maximum cuttings concentration condition is calculated based on the measured bottom-hole equivalent circulation density and pure drilling time. Using the technical solution of this invention, it is determined whether the current drilling fluid discharge rate and drill string rotation speed meet the wellbore cleaning requirements. If not, the current drilling fluid discharge rate and drill string rotation speed are optimized and adjusted. The standpipe circulation time is determined after meeting the wellbore leave requirements, thus determining the wellbore cleaning time. The proposed method for optimizing wellbore cleaning cycle time can provide quantitative calculation and analysis of wellbore cleaning construction parameters and procedures, and can provide simulation technology support for automated drilling safety monitoring in the future.

[0117] Figure 3 This is a schematic diagram of a wellbore cleaning cycle time optimization device provided in an embodiment of the present invention. The technical solution of this embodiment can be applied to the optimization of wellbore cleaning cycle time. This device can be implemented by software and / or hardware and is generally integrated into any electronic device with network communication capabilities, including but not limited to: servers, computers, personal digital assistants, etc. Figure 3As shown, the wellbore cleaning cycle time optimization device provided in this embodiment may include: a drilling data determination module 310, a cleaning requirement 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 during target wellbore cleaning; the drilling data includes wellbore size, drilling fluid discharge rate, drilling fluid density, and drill string rotation speed;

[0119] The cleaning requirement determination module 320 is used to determine the drilling fluid annular return velocity vector sum and cuttings settling velocity based on the drilling data, and to determine whether the drilling data meets the target wellbore cleaning requirements based on the drilling fluid annular return velocity vector sum and cuttings settling velocity.

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

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

[0122] The axial velocity of the drilling fluid is determined based on the drilling fluid discharge rate.

[0123] The circumferential flow velocity of the drilling fluid is determined based on the drill string rotation speed;

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

[0125] Optionally, based on the above embodiments, the cleaning requirement determination module is further configured to:

[0126] Determine the particle Reynolds number of the cuttings during target wellbore cleaning, and determine the numerical range of the particle Reynolds number;

[0127] Based on the numerical range of the particle Reynolds number, the target rock cuttings settling velocity calculation formula is determined from the preset rock cuttings settling velocity calculation formula, and the target rock cuttings settling velocity is determined.

[0128] The formula for calculating the settling velocity of rock debris varies depending on the numerical range of the particle Reynolds number.

[0129] Optionally, based on the above embodiments, the cleaning requirement determination module is further configured to:

[0130] The cuttings delivery ratio is determined based on the combined annular return velocity vector of the drilling fluid and the cuttings settling velocity, and it is determined whether the cuttings delivery ratio is greater than a preset cuttings delivery ratio threshold.

[0131] If the cuttings delivery ratio is greater than a preset cuttings delivery ratio threshold, then the drilling data is determined to meet the target wellbore cleaning requirements.

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

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

[0134] Determine the maximum mechanical rotation speed during target wellbore cleaning, and determine the maximum annular cuttings concentration under the maximum mechanical rotation speed condition;

[0135] The density of the annular fluid-solid mixture drilling fluid is determined based on the drilling fluid density and the maximum annular cuttings concentration.

[0136] The target wellbore cleaning cycle time 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] Optionally, based on the above embodiments, the cycle time determination module is further configured to:

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

[0139] The proportion of pure drilling time to stand-up time is determined based on the measured bottom hole equivalent circulation density and the density of the annular liquid-solid mixed drilling fluid.

[0140] The standpipe circulation time is determined based on the ratio of pure drilling time to standpipe time and the pure drilling time, and the target wellbore cleaning circulation time is determined based on the standpipe circulation 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 embodiments of the present invention, and has the corresponding functions and beneficial effects of executing the wellbore cleaning cycle time optimization method. For details, please refer to the relevant operations of the wellbore cleaning cycle time optimization method in the foregoing embodiments.

[0142] Figure 4This 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 processors, cellular phones, smartphones, 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 illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

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

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

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

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

[0147] Various embodiments 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-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0148] Computer programs used to implement 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, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

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

[0150] To provide interaction with a user, the systems and techniques described herein can 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 pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0151] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0152] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through a communication network. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0153] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and no limitation is imposed herein.

[0154] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for optimizing wellbore cleaning cycle time, characterized in that, The method includes: Determine the drilling data during target wellbore cleaning; the drilling data includes wellbore size, drilling fluid flow rate, drilling fluid density, and drill string rotation speed; Based on the drilling data, the final vector sum of the drilling fluid annular return velocity and the cuttings settling velocity are determined, and it is then determined whether the drilling data meets the target wellbore cleaning requirements based on the final vector sum of the drilling fluid annular return velocity and the cuttings settling velocity. Specifically, the axial flow velocity of the drilling fluid is determined based on the drilling fluid displacement; the circumferential flow velocity of the drilling fluid is determined based on the drill string rotation speed; and the axial flow velocity and the circumferential flow velocity of the drilling fluid are vector-superimposed to determine the final vector sum of the drilling fluid annular return velocity. When the drilling data meets the target wellbore cleaning requirements, the target wellbore cleaning cycle time under the maximum annular cuttings concentration condition is determined based on the drilling data. Specifically, 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, including: The cuttings delivery ratio is determined based on the combined annular return velocity vector of the drilling fluid and the cuttings settling velocity, and it is then determined whether the cuttings delivery ratio is greater than a preset cuttings delivery ratio threshold. If the cuttings delivery ratio is greater than the preset cuttings delivery ratio threshold, it is determined that the drilling data meets the target wellbore cleaning requirements. If the cuttings delivery ratio is not greater than the preset cuttings delivery ratio threshold, the drilling fluid discharge rate and drill string speed are modulated until the cuttings delivery ratio is greater than the preset cuttings delivery ratio threshold. Wherein, when the drilling data meets the target wellbore cleaning requirements, the target wellbore cleaning target circulation time under the condition of maximum annular cuttings concentration is determined based on the drilling data, including: Determine the maximum mechanical rotation speed for cleaning the target wellbore, and determine the maximum annular cuttings concentration under the maximum mechanical rotation speed condition; determine the annular fluid-solid mixture drilling fluid density based on the drilling fluid density and the maximum annular cuttings concentration; determine the measured bottom hole equivalent circulation density and pure drilling time; determine the proportion of pure drilling time to standpipe time based on the measured bottom hole equivalent circulation density and the annular fluid-solid mixture drilling fluid density; determine the standpipe circulation time based on the proportion of pure drilling time to standpipe time and the pure drilling time, and determine the target wellbore cleaning circulation time based on the standpipe circulation time.

2. The method according to claim 1, characterized in that, Determining the cuttings settling velocity based on the drilling data includes: Determine the particle Reynolds number of the cuttings during target wellbore cleaning, and determine the numerical range of the particle Reynolds number; Based on the numerical range of the particle Reynolds number, the target rock cuttings settling velocity calculation formula is determined from the preset rock cuttings settling velocity calculation formula, and the target rock cuttings settling velocity is determined. The formula for calculating the settling velocity of rock debris varies depending on the numerical range of the particle Reynolds number.

3. A device for optimizing wellbore cleaning cycle time, characterized in that, The device includes: The drilling data determination module is used to determine the drilling data during target wellbore cleaning; the drilling data includes wellbore size, drilling fluid flow rate, drilling fluid density, and drill string rotation speed; The cleaning requirement determination module is used to determine the drilling fluid annular return velocity vector sum and cuttings settling velocity based on the drilling data, and to determine whether the drilling data meets the target wellbore cleaning requirements based on the drilling fluid annular return velocity vector sum and cuttings settling velocity; wherein, the drilling fluid axial velocity is determined based on the drilling fluid discharge rate; the drilling fluid circumferential velocity is determined based on the drill string rotation speed; and the drilling fluid axial velocity and drilling fluid circumferential velocity are vector-superimposed to determine the drilling fluid annular return velocity vector sum. The cycle time determination module is used to determine the target cycle time for wellbore cleaning under the condition of maximum annular cuttings concentration based on the drilling data when the drilling data meets the target wellbore cleaning requirements. The cleaning requirements determination module is specifically used for: The cuttings delivery ratio is determined based on the combined annular return velocity vector of the drilling fluid and the cuttings settling velocity, and it is then determined whether the cuttings delivery ratio is greater than a preset cuttings delivery ratio threshold. If the cuttings delivery ratio is greater than the preset cuttings delivery ratio threshold, it is determined that the drilling data meets the target wellbore cleaning requirements. If the cuttings delivery ratio is not greater than the preset cuttings delivery ratio threshold, the drilling fluid discharge rate and drill string speed are modulated until the cuttings delivery ratio is greater than the preset cuttings delivery ratio threshold. The loop time determination module is specifically used for: Determine the maximum mechanical rotation speed for cleaning the target wellbore, and determine the maximum annular cuttings concentration under the maximum mechanical rotation speed condition; determine the annular fluid-solid mixture drilling fluid density based on the drilling fluid density and the maximum annular cuttings concentration; determine the measured bottom hole equivalent circulation density and pure drilling time; determine the proportion of pure drilling time to standpipe time based on the measured bottom hole equivalent circulation density and the annular fluid-solid mixture drilling fluid density; determine the standpipe circulation time based on the proportion of pure drilling time to standpipe time and the pure drilling time, and determine the target wellbore cleaning circulation time based on the standpipe circulation time.

4. An electronic device, characterized in that, include: One or more processors; 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 1-2.

5. A storage medium containing computer-executable instructions, characterized in that, The computer-executable instructions, when executed by a computer processor, are used to perform the wellbore cleaning cycle time optimization method as described in any one of claims 1-2.

Images