• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
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  • 优先权
    • 专利摘要:
    MODELING AND SIMULATION OF COMPLETE DRILLING COLUMNS. A method for predicting the behavior of a drilling assembly, comprising: generating a mathematical representation of the geometry of each of the plurality of components of a drilling assembly, the plurality of components including a plurality of cutters, and one or more additional components configured to at least: support the plurality of cutters and operatively connect the plurality of cutters to the drill string, one or more additional components including a drill bit; simulate one or more operating conditions incident on the representation of the drilling assembly and simulate an interaction between the plurality of components and a soil formation; and predicting physical responses of the drill assembly representation under one or more conditions.
    公开号:BR112014004826B1
    申请号:R112014004826-6
    申请日:2012-08-23
    公开日:2021-05-25
    发明作者:Christian Herbig；Hanno Reckmann；Bernhard Meyer-Heye；Frank Schuberth；Carmel Zouheir El Hakam；Jonathan Mackey Hanson；Reed W. Spencer；Jayesh Rameshlal Jain
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    CROSS REFERENCE FOR RELATED ORDERS
    [001] This application claims the benefit of US Application No. 13/220087, filed August 29, 2011, which is incorporated herein by reference in its entirety. BACKGROUND OF THE INVENTION 1. Area of invention
    [002] The present invention relates to drill strings. More specifically, it refers to apparatus and methods for modeling the dynamic behavior of drill strings. two . Description of Related Art
    [003] Various types of drill strings are used in a well for the exploration and production of hydrocarbons. The drill string generally includes a drill pipe and a bottom drill assembly. The bottom drilling assembly contains drill collars, which can be instrumented, which can be used to obtain measurements during drilling or during recording, for example.
    [004] When used in the drillhole, the drill string can be subjected to a wide variety of forces or loads. Because the drill string is in the well, the loads are not visible and can affect the dynamic behavior of the drill string. An immediate result of invisible charges may be unknown. If loads are detrimental, then continued operation of the drill string can cause damage or unreliable operation.
    [005] Drill string testing can be performed to simulate the loads affecting the drill string and drill shaping. However, such modeling may not be able to completely predict the behavior of the drill string in its entirety. BRIEF SUMMARY OF THE INVENTION
    [006] A method designed to predict the behavior of a drilling assembly, which includes: generating a mathematical representation of a geometry of each plurality of components of a drilling assembly, the plurality of components including a plurality of cutters, and a or more additional components configured to at least: support the plurality of cutters and operatively connect the plurality of cutters to the drill string, one or more additional components including a drill bit; simulate one or more operating conditions incident on the representation of the drilling assembly, and also simulate an interaction between the plurality of components and a soil formation; and predict physical responses of the drill assembly representation under one or more of these conditions.
    [007] A computer program product designed to predict the behavior of a drilling assembly, which includes a tangible storage medium, readable by a processing circuit, storing instructions for its realization, through a method. The method includes: generating a mathematical representation of a geometry of each of the plurality of components of a drilling assembly, the plurality of components including a plurality of cutters, and one or more additional components configured to at least: support the plurality of cutters, operatively connecting the plurality of cutters to the drill string, one or more additional components including a drill bit; simulate one or more operating conditions, incident on the representation of the drilling set, and simulate, however, an interaction between the plurality of components and a soil formation; and predicting physical responses of the drill assembly representation under one or more of these conditions.
    [008] A system designed to estimate the behavior of a drilling assembly during the drilling operation, which includes a drilling assembly, including at least one drill bit connected to a drill string, the assembly being configured to be placed in a drilling well; a plurality of sensors operatively associated with the drilling assembly, and a processor in communication with said plurality of sensors. The processor is configured to: generate a mathematical representation of a geometry of each of the plurality of components of a perforation assembly, the plurality of components including a plurality of cutters, and one or more additional components configured to at least: support the the plurality of cutters and operatively connecting the plurality of cutters to the drill string, one or more additional components including a drill bit; simulating one or more operating conditions incident upon the representation of the drilling assembly, and simulating an interaction between the plurality of components and a formation, and predicting the physical responses of the representation of the drilling assembly under one or more of these conditions. BRIEF DESCRIPTION OF THE DRAWINGS
    [009] The object considered as the invention is particularly highlighted and distinctly claimed in the claims at the end of the specification. The following and other features and advantages of the invention are evident from the following detailed description taken in conjunction with the attached drawings, where similar elements are numbered in the same way, as follows:
    [0010] FIG. 1 is an exemplary embodiment of a drilling system which includes a drill string disposed in a drillhole in a soil formation;
    [0011] FIGS. 2A and 2B are perspective views of exemplary embodiments of a drill bit belonging to the system of FIG. 1;
    [0012] FIG. 3 is a flowchart representing an embodiment of a method of predicting and/or simulating the behavior of a drill string using a drill string model;
    [0013] FIG. 4 is an illustration of a part of an exemplary geometric model of a perforation assembly; and
    [0014] FIG. 5 is an illustration of an exemplary part of the geometric model of a perforation assembly; and
    [0015] FIG. 6 is an illustration of an example of the model of FIG. 3 , illustrating the exemplary results of a simulation of the behavior of a drilling set. DETAILED DESCRIPTION OF THE INVENTION
    [0016] Exemplary techniques for estimating or predicting the dynamic behavior of a drilling set and/or a static parameter associated with the drilling set are referred to. The techniques, which include systems and methods, use a mathematical model of a drilling set designed to simulate the forces and loads experienced by the composition of the drill string in a downhole environment, as well as interactions between the drilling set. with the well environment (eg the wall, casing, well formation materials and/or well fluid). In one embodiment, the methods and associated software are intended for generating a mathematical model (e.g., a finite element model) of the drilling assembly, so as to provide a complete model of various components of the drilling assembly, and simulate the interaction between drilling assembly components and the well environment. Methods include modeling components between the drill cutters and the drill string, such as the crown, body, gage and others, modeling the interaction of these components with the well environment. Components can include structural components for supporting the drill, and cutters, as well as for attaching the drill to the drill string. The template may also include additional components such as a mandrel, cutter mandrel and a mandrel body component. In one embodiment, the analysis model is made by doing a time domain analysis of the model.
    [0017] Referring to FIG. 1 is an exemplary embodiment illustrating a bottom drilling system 10 disposed in drillhole 12. Drill string 14 is disposed in drillhole 12, which penetrates at least one earth formation 16. hole 12 is designated in FIG. 1 as being of constant diameter, the drillhole is not so limited. For example, well 12 can be of different diameters and/or direction (eg slope and azimuth). The drill string 14 is created from, for example, a tube or several sections of tube. System 10 and/or drill string 14 include a drill assembly 18. Various measurement instruments may also be incorporated into system 10 in order to affect measurement regimes such as wire measurement or logging applications in drilling. (LWD).
    [0018] The drill assembly 18, which may be configured as a bottom assembly (BHA), includes a drill bit 20, connected to the lower end of the drill string 14, via various components of the drill assembly. Drill assembly 18 is configured so that it can be used within a drill hole 12 from a drill rig 24. The components of the drill assembly include various components designed to provide structural and operational support for the drill bit 20 , as well as its drill cutters 22, and also operatively connecting the drill 20 and cutters 22 to the drill string 14. Exemplary components of the drill assembly include a drill body 26 operatively connected to the cutters 22, a drill motor. drilling 28 (also referred to as a mud engine) and a stabilizer or chuck 30.
    [0019] A processing unit 32 is linked in operative communication with the drilling assembly 18 and may be located, for example, at a surface location, at a subsea location and/or at a surface location on a marine platform or on a maritime vessel. The processing unit 32 can, if desired, also be incorporated into the drill string 14 or the drill assembly 18, or even arranged at the bottom of the well. The processing unit 32 can be configured to perform functions such as controlling the drilling set 18, transmitting and receiving data, transmitting and receiving measurement data, controlling the drilling set 18 and carrying out simulations referring to drilling set 18, using mathematical models. The processing unit 32, in one embodiment, includes a processor 34, a data storage device (or a computer readable medium) 36 for storing data, computer templates and/or programs, or software 38 .
    [0020] In one embodiment, the drill 20 and/or the drilling set 18 includes one or more sensors 40 and related circuitry so as to estimate one or more parameters related to the drilling set 18. For example, a distributed sensor system (DSS) is disposed on drill assembly 18 and includes a plurality of sensors 40. Sensors 40 perform measurements associated with dynamic movement of drill assembly 18 and/or drill string 14, or with a static parameter associated here, and can also be configured to measure environmental parameters of temperature and pressure. Examples of limitless measurements performed by sensors include accelerations, velocities, distances, angles, forces, moments and pressures. As an example of distribution of sensors, they can be distributed over a drill string and tools (such as a drill) arranged at the distal end of the drill string 14. In one embodiment, the sensors 40 are coupled to a unit downhole electronics 42, which may receive data from sensors 40, transmitting it to a processing system such as processing unit 32. Different techniques for transmitting data to processing unit 32 may be used, such as mud pulse, electromagnetic, acoustic telemetry, or a wired tube.
    [0021] As used herein, "dynamic motion" refers to a change in the stationary motion of the drill string. Dynamic motion can include vibrations and resonances. The term "static parameter" refers to a parameter associated with a drill string. The static parameter is generally a physical condition experienced by the drill string. Non-limiting examples of the static parameter include a displacement, a force or load, a moment (for example, the torque or bending moment) or a pressure.
    [0022] An exemplary embodiment of a rotary soil probing drill 20 is shown in FIG. 2A. Drill 20 includes a crown 44 and a drill body 26. The drill body 26 may include various structural components, such as a shank 46 secured to the crown 44 by a weld 48, a steel plate 50 and a connecting mechanism, such as a threaded connection 52 for operatively connecting the drill bit 20 to the drill string, or other components, such as a mud motor 28 or a chuck 30. Other components include a gage 53 disposed adjacent to the ring 44. The gage 53 may include various components such as gauge pads and gauge trimmers. Other examples of components include components that cause friction or contact with the well wall material generally, such as Tracblocks, ovoids, anti-wear knots, and the like.
    [0023] The drill body 26 includes wings or blades 54, separated by outer channels or conduits, also known as garbage grooves 56. Internal fluid passages 58 may be included, extending between the outer surface of the crown 44 and a longitudinal hole 60, which extends through drill body 26. A plurality of cutters 62 (eg PDC cutters) are disposed on ring 44.
    [0024] The embodiment illustrated in FIG. 2A is a fixed cutter bit, such as a polycrystalline compact diamond (PDC) bit. However, drill bit 20 is not limited to the embodiments described herein, and may be of any type or a ground drill bit, such as a rotary drag bit, or a conical roller bit.
    [0025] For example, as illustrated in FIG. 2B, drill 20 may include a rotary drill having cutters attached to the cones. In this example, the drill body includes cone containers 64 and inserts 66 or other cutting elements that interact with formation 16 during drilling. Referring to FIG. 3, a method 70 for predicting the parameters and/or behavior of the drill string assembly is described. The method can be performed by a computer processing system (eg processing unit 32), through programs or software, to generate a dynamic drill string model, which can be used to investigate or predict the performance and behavior of the ensemble, relative to the selected well bottom, and drilling conditions. Examples of components of such a computer processing system include, without limitation, at least one processor, storage, memory, input and output devices, and the like. At least some parts of the process 70 can be carried out using the data previously generated and stored, or it is possible to carry out the process using data generated in real time, during an underground operation or experimental operation of drilling components such as the drilling set 18. Method 70 includes one or more steps 71-74. In one embodiment, method 70 includes performing all steps 71-74 in the order described. However, certain steps can be omitted, and other steps can be added, or the order of steps can be changed.
    [0026] In the first step 71, input parameters, including geometric data (eg, size and shape) that describe the drill set 18, are selected to be input into a mathematical model of the drill set 18. The model uses the geometric data to generate representations of the geometry of one or more of the components of the drilling assembly 18, and interactions between the components of the drilling system (e.g., drills, motors, thrusters, stabilizers, well, drilling fluid), as well as interactions between the drill assembly 28 and drillhole wall fluid and/or formation materials during drilling operations. The model is provided to allow users to simulate the conditions and component interactions that arise during a drilling operation.
    [0027] An exemplary simulation model is generated using the finite element method. In one embodiment, a plurality of node elements are generated from the geometric data which correspond to the shape or geometry of different parts of the perforation assembly 18.
    [0028] In another embodiment, the drill string assembly is modeled as a three-dimensional model through finite elements such as geometrically linear beams or mass elements. Nodes are assigned to the various components of the drill string assembly. For example, nodes can be used to simulate the geometric shape and density of the drill bit, cutters, and various components of the drill assembly and/or drill string. Such components include the various support structures designed to physically and operationally support the drill cutters and/or connect the cutters to the drill string. Exemplary components that could become model elements include drill body 26, shank 46, connector 52, blades, 54, steel blank 50, 64 cone roller shells, 66 cone roller inserts, 53 gauge, slurry motor 28 and chuck 30. Other components include gauge pads, gauges, Tracblocks trimmers, ovoids, wear knots and others. In one embodiment of the invention, the template includes (e.g., as template elements) any drilling assembly components (including crown components and body components) in contact by friction against the casing of the well wall drilling, or any other form of contact with the forming material. In another embodiment, the template includes any surface or geometry of the drill body which is not made up of cutters, such as super abrasive cutters. In yet another embodiment, the model includes a plurality of nodes, corresponding to a configuration of the drill body 26. The nodes may be included for the drill string portion, the mud motor 28 and, optionally, one or more chucks 30.
    [0029] In addition, the model can include input parameters, regarding the formation and/or well. For example, wellbore diameter and direction (eg slope and azimuth) as well as changes in borehole can be introduced into the model. Such well parameters can be made from measurements taken during (eg real-time) or after drilling, such as real-time gauge measurements. Such parameters can also be a result of the model, predicting the quality of the drilling well (eg spiral well). Forecast can include new azimuth and slope, build rate, etc.
    [0030] This embodiment of the model provides greater accuracy of predictions, modeling the structure of the drill body between the drill and the drill string, in addition to the drill string and the drill (for example, in the crown and cutters). By modeling the structural support of the drill (the drill body), additional information about vibration, deformation and other behaviors can now be detected that would have previously been ignored. In addition, the friction between the drilling assembly components and the formation can be modeled, and different friction models can be applied, in order to determine the friction characteristics, such as Coulomb friction or type friction characteristics. Strbeck. The model can be used to predict behaviors of friction surfaces so that these surfaces can be designed to improve drilling quality, for example, to improve tool face control or direction, in order to reduce the friction of the exposure surface and the sliding effect. Furthermore, additional damping can be designed to provide lateral stability. These and other friction surface benefits can be optimized using the computer model.
    [0031] An example of a geometric model of a perforation assembly is shown in FIG. 4 . In this example a finite element model 80 of drill assembly components 18 is illustrated. The model 80 includes elements representing cutters 84 and parts of a drill body 86 and other components 82 . The model 80 may also show various forces 88 incident on the assembly. This example is only a partial example, as the model may include other components of the drill string as well as additional forces and parameters from various components of the drill string. FIG. 4 illustrates only a portion of the model 80, which may include other components such as a drill body, a drill blank and/or a drill gauge. In another embodiment, the components 82 include any components of the drilling assembly, and are in contact with the well wall (and/or casing) and with formation materials and/or well fluids. FIG. 5 illustrates an example of a finite element model 80 where components 82 are crown elements.
    [0032] In one embodiment, each node of the model is given six degrees of freedom of movement (three translations, three rotations), being confined within an area representing well 12, using, for example, a penalty function. Equations of motion can be used in conjunction with these degrees of freedom and can be integrated through adaptive, implicit or explicit, fixed or variable time steps.
    [0033] For example, the deformations of each node, generated to represent the drilling set 18 are measured by three nodal displacements and three rotations, recorded as follows: Lateral displacements: u1,u2 Lateral rotations: θi, 02 Axial displacement: u3 Axial rotation: θ3
    [0034] This formulation, together with the absence of geometric linearity, allows the analysis of associated lateral, axial and torsional vibrations, in the frequency and time domain, also allowing the calculation of, for example, buckling loads and post behavior. -buckling.
    [0035] In the second stage 72, various operating, drilling and force parameters are applied to the model in order to simulate a drilling operation. Systems of non-linear equations of associated motion are used, which are integrated over time, in order to obtain transient and constant state displacements, loads and stresses. Various input forces can be used, such as weight-on-drill, drilling rotation speed, fluid pressure, mass unbalance forces, axial stresses, radial stresses, weights of various components, and structural parameters such as rigidity.
    [0036] Other parameters that may be applied include parameters related to the interaction between the components of the model and the well environment, which include a casing wall, the fluid and/or the well formation. The well fluid can include any type of fluid detected in the drilling well, such as: drilling mud, steam, formation fluids such as water, oil, gas and other hydrocarbons. Examples of such interaction parameters include formation rate (eg rock) by removal of components such as the blades and drill body. Including the individual removal rates for different parameters, additional details are provided as the drill body may be responsible for some removal, and this removal can be modeled at a different rate than the cutters. Other interaction parameters include forces experienced by the drill assembly and/or drill string due to retraction from contact with the bore wall, such as the faction forces experienced by different model components due to contact with the bore wall, fact that generates additional torque in the drilling set. Other parameters include the effects of interaction with the drilling wall during the drilling operation. For example, the rotation rate (eg RPM) or the penetration rate may be limited due to contact between the drill assembly components and the well wall. Models are not limited in predicting faction forces. For example, the interaction between the piercing assembly (eg rubbing the body and crown surfaces) is not limited to modeling to machete forces. Any forces resulting from contact with rock and other formation materials can be modelled.
    [0037] In one embodiment, using degrees of motion and input force values, an exemplary nonlinear system of differential equations is derived:
    displacements/revolutions of nodes M: mass matrix FF: forces distributed from the mud Fw: forces of contact with the wall FG: non-linear elastic forces R: static forces (buoyancy weight, WOB ... ) FE: excitation forces (mass imbalances, ... )
    [0038] The knots and forces described herein are exemplary, and are not intended to be limiting. Any desired forces, being suitable to be modelled, can be used.
    [0039] The equations mentioned above are solved in the time domain to evaluate the dynamic response of the structures modeled by the nodes. In one embodiment, the equations are solved by a Newmark integration scheme. Other methods of solving equations can be used, including but not limited to the finite difference method. In one embodiment, equations can be solved in the frequency domain, for example to estimate lateral dynamics, or to provide data for static cases, or steady-state cases.
    [0040] In the third step 73, the simulated behavior of the modeled drill string set is estimated, generated from the model results. This behavior can be forwarded to dynamic events such as wells and can be classified as having one or more models such as axial events (eg little jump, Kelly jump), side events, twist events (eg stick-effect). slip) and spiral effect events.
    [0041] Other behaviors include predictions of changes in the well (eg diameter, azimuth and slope) as well as changes in well quality (eg spiraling along the gauge). Forecasts can include outputs such as new azimuth and slope, build rate, and others.
    [0042] The simulated behavior includes physical responses, including (but not limited to) the dynamic behavior of the drill string assembly/bit assembly; the static solution of the drill string/bit set, the rate of development of the drill string/bit set in a given formation, due to the dynamic behavior of the drill string/bit set, and the rate of development of the drill string. drill/drill set in a given formation due to static solution of the drill string/drill set.
    [0043] Referring to the Figures. 5A and 5B, an exemplary model is illustrated which demonstrates the modeled behavioral response of a drilling assembly during a simulated drilling operation. In this example, the results are presented for a finite element model of a 7,875 inch CID 627 bit in a BHA in vertical drilling. Drilling simulations observed are at a penetration rate (ROP) of 10 ft/h through hard rock at 45 RPM (shown in FIG. 4A) and 90 RPM (shown in FIG. 4B). The weight on the bit (WOB) needed to drill in this ROP was enough to deform the collar, and the friction coefficient between the collars and the well was high enough to generate a spiral effect in the BHA. The side and front views at 45 RPM show the shape of the collars processed around the well. The upper portion of the BHA essentially acted as a rigid body at this slow speed. The side and front views at 90 RPM show a slightly different result as the BHA took on a more helical shape. Although the models discussed here refer to fixed cutter bits, they are not limited. For example, the model may include components from a cone roller drill or a rotary drag drill.
    [0044] In the fourth step 74, in another embodiment, the input parameters are modified as needed to change the design of the drill string (for example, the bit, BHA and/or other components of the drill string) so that the simulated behavior stays within the selected limits. Such design changes may include the shape or diameter of the drill body or other components of the drill assembly, the modification or addition of stabilization structures to the drill body or part of the drill string. Other binding changes may include changes in the weight, diameter, thickness and/or stiffness of tubular elements, and change in exposure, side and/or front of the cutters. Other parameters that can be changed include operating parameters such as rotation speed and weight on the drill. After changing these parameters, the behavior is again simulated, in order to determine if stability has improved and/or increased. These modifications can be made to the model, with the model being simulated iteratively, in order to optimize the drill string design and/or operating parameters, as well as experiments and simulation optimization projects (for example, Mount Simulation Carlos).
    [0045] In one embodiment, the mathematical model is validated with motion measurements or static parameters recorded during the operation of a drilling assembly. For example, during a drilling operation, a dynamic or static parameter movement is estimated through the model referring to the location where the measurement is performed. Dynamic or static parameter movement is then compared with the measurement. If the difference between the estimated dynamic movement, or static parameter, and the measurement is within a certain tolerance, the mathematical model is validated. Loads, such as forces or moments, imposed on the drill string in the mathematical model can also be validated in this way. Measurements can be updated continuously or periodically while the drill assembly is running. Sensors distributed on the drill string (i.e., operatively associated with the drill string), such as sensors 40, can be used to provide dynamic motion or static parameter measurements. Model validation can be performed after drilling, or in real-time during a drilling operation.
    [0046] In another embodiment, the model can be used to simulate the behavior of the drill string assembly before a drilling operation is performed, in real time, during a drilling operation and/or after an operation drilling is completed. For example, real-time dynamic events can be measured by the sensors and transmitted to the processor, which applies said measurements to the model, to assess the performance of the drill string assembly. The results of the present application could be used to change drilling parameters, or otherwise control the drilling operation through, for example, the processing unit 32. In one embodiment, the generation of measurement data in "Real time" is effected to provide the generation of data at a rate that is useful or sufficient to provide control functions, or decision making, during, or simultaneously with, drilling operations processes. Consequently, it should be recognized that the expression "in real time" is to be taken in its context, not necessarily indicating instantaneous determination of data or making other suggestions about the temporal frequency of data collection and determination.
    The systems and methods described herein offer several advantages over known techniques in the art. For example, drill assembly models can be generated and tested, which include a more complete description of the drill assembly than has been achieved by previously known techniques, which typically limit models to the inclusion of a drill string and one bit (ie the crown and one or more cutters). The systems and methods described here allow for more complete models to be provided, including the bit body and other parts of the body of the drilling set (for example, a mud motor), which leads to more realistic models and more simulation results. accurate.
    [0048] Generally, some of the teachings described here are reduced to an algorithm, which is stored in optical reading systems. The algorithm is implemented by the computer processing system and offering the process operators the desired answer.
    [0049] In support of the instructions contained herein, the various components of the analysis can be used, including digital and/or analog systems. Digital and/or analogue systems can be included, for example, in the downhole electronic unit 42, or in the processing unit 32 . Systems can include components such as: processor, analog-digital converter, digital-to-analog converter, storage media, memory, input, output, communication link (wired, wireless, pulsed mud, optical or other), user interfaces , software programs, signal processor (digital or analog) and other components (such as resistors, capacitors, inductors and others), in order to provide the operation and analysis of the apparatus, and the methods disclosed herein, under any of the several well-preferred forms of art. It is considered that these instructions can be, but not necessarily, implemented, in connection with a set of computer executable instructions, stored in a computer readable system, which includes memory (ROM, RAM), optical (CD-ROM), or magnetic (floppy disks, hard disk drives), or any other type, which when executed allows a computer to implement the method of the present invention. These instructions may provide for equipment operation, control, data collection and analysis, and other functions deemed relevant by a system designer, owner, user, or third parties, in addition to the functions disclosed herein.
    [0050] [0049] In addition, various other components may be included and convened for consideration of aspects of the teachings contained herein. For example, a power supply (for example, at least one of a generator, a remote supply and a battery), cooling component, heating components, motive force (such as a translation force, a driving force, or a force rotation), digital signal processor, analog signal processor, sensor, magnet, antenna, transmitter, receiver, transceiver, controller, optical unit, electrical or electromechanical unit, may be included in support of the various aspects referred to here, or in support of other functions, in addition to those described here.
    [0051] The elements of the embodiments have been presented, accompanied by the articles "o" or "an". Articles are intended to signify that there is one or more of the elements. The terms "including" and "having" and their derivatives mean that it may be included, so that there may be others in addition to the additional elements referred to. The term "or" when used with a list of at least two articles is intended to mean any item or combination of elements.
    [0052] It will be recognized that the various components or technologies may provide some necessary or beneficial functionality or functionality. Accordingly, these functions and features as necessary will serve to support the appended claims and variations thereof, and therefore recognized as being inherently included as part of the disclosed processes herein and a described part of the invention.
    [0053] While the invention has been described with reference to exemplary embodiments, it will be understood that various modifications can be made, and equivalents substituted for elements thereof, without departing from the scope of the invention. Additionally, many modifications will be appreciated in adapting a particular instrument, situation, or material to the teachings of the invention without departing from the essential scope thereof. It is therefore intended that the invention is not limited to the particular embodiment described, considered to be the most suitable for carrying out this invention, but that the invention includes all embodiments falling within the scope of the appended claims.
    权利要求:
    Claims (9)
    [0001]
    1. Method (70) of predicting the behavior of a drill assembly (18), characterized by: generating a mathematical representation of a drill bit (20), the representation including a geometry of each of the plurality of cutters (22) and a geometry of one or more non-cutting drill bit components (20), the one or more non-cutting components including at least a portion of a drill bit crown (44); simulate one or more operating conditions incident on the drill assembly (18), and simulate contact between the drill bit (20) and at least one of a well wall and a ground formation (16), in which the contact simulation includes: simulating interaction between the plurality of cutters (22) and at least one of the well wall (12) and the earth formation (16) using a first interaction parameter associated with forces experienced by the plurality of cutters (22) , wherein the plurality of cutters (22) is simulated as a first component to which the first interaction parameter is applied, and simulate interaction between the one or more non-cutting components of the drill bit (20) and at least one of the wall of well and earth formation (16) using a second interaction parameter associated with different forces experienced by the one or more non-cutting components, the second interaction parameter associated with frictional forces experienced by the the surfaces of the one or more non-cutting components due to friction against at least one of the well wall and the earth formation (16), wherein the non-cutting components of the drill bit (20) are simulated as a separate component to which the second interaction parameter is applied, the first interaction parameter and the second interaction parameter including different formation material removal rates; and predicting physical responses of the drill assembly (18) to the one or more conditions and simulated contact.
    [0002]
    2. Method (70), according to claim 1, characterized in that the crown (44) of the drill bit (20) has the cutters attached to it.
    [0003]
    3. Method (70), according to claim 1, characterized in that the mathematical representation is a finite element model, and generating the mathematical representation includes generating a plurality of nodes, where the plurality of nodes represents the geometry.
    [0004]
    4. Method according to claim 1, characterized in that the one or more non-cutting components include a drill bit body (26).
    [0005]
    5. Method (70), according to claim 1, characterized in that the one or more operating conditions include at least one drilling parameter, a force, a load, a moment and a torque.
    [0006]
    6. Method (70) according to claim 1, characterized in that the physical responses include dynamic behavior of the drill string (14) and the drilling assembly (18), a static solution of the drill string (14) and of the drill string (18), an accumulation rate of the drill string (14) and the drill string (18) in an earth formation (16) due to the dynamic behavior and accumulation rate of the drill string and of the perforation assembly (18) in the formation of earth (16) due to the static solution.
    [0007]
    7. System (10) for estimating a behavior of a drilling assembly (18) during a drilling operation, the system (10) characterized by: a drilling assembly (18) including at least one connected drill bit (20) to a drill string (14), the drill assembly (18) configured to be disposed in a well (12); a plurality of sensors (40) operatively associated with the piercing assembly (18); and a processor (32) in communication with the plurality of sensors (40), the processor (32) being configured to: generate a mathematical representation of a drill bit (20), the representation including a geometry of a plurality of cutters and one or more non-cutting drill bit components (20), the one or more non-cutting components including at least a portion of a drill bit crown (44); simulate one or more operating conditions incident on the drill assembly (18) and simulate a contact between the drill bit (20) and at least one of a well wall and an earth formation (16), in which the simulation includes: simulating interaction between the plurality of cutters (22) and at least one of the well wall and the earth formation (16) using a first interaction parameter associated with forces experienced by the plurality of cutters (22) where the plurality of cutters (22) is simulated as a first component to which the first interaction parameter is applied, and simulate interaction between the one or more non-cutting components of the drill bit (20) and at least one of the well wall and of earth formation (16) using a second interaction parameter associated with different forces experienced by the one or more non-cutting components, the second interaction parameter associated with frictional forces experienced by the surfaces. ie the one or more non-cutting components due to friction against at least one of the well wall and the earth formation, wherein the non-cutting components of the drill bit (20) are simulated as a separate component to which the second parameter of interaction is applied, the first interaction parameter and the second interaction parameter including different rates of formation material removal; and predicting physical responses of the drill assembly (18) to the one or more conditions and simulated contact.
    [0008]
    8. System (10), according to claim 7, characterized in that the mathematical representation is a finite element model and generating the mathematical representation includes generating a plurality of nodes, in which the plurality of nodes represents the geometry.
    [0009]
    9. Method (70), according to claim 7, characterized in that the plurality of sensors (40) are configured to measure the downhole parameters associated with the drilling assembly (18), and the processor (32) be configured to enter downhole parameters to simulate the physical responses of the drill assembly (18).
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    US20190169972A1|2019-06-06|
    US10851637B2|2020-12-01|
    GB2509268A|2014-06-25|
    GB201404828D0|2014-04-30|
    NO20140146A1|2014-02-19|
    BR112014004826A2|2017-04-04|
    US10227857B2|2019-03-12|
    SA112330809B1|2016-02-17|
    NO345447B1|2021-02-01|
    WO2013032863A1|2013-03-07|
    GB2509268B|2018-08-22|
    US20130054203A1|2013-02-28|
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    法律状态:
    2018-12-11| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-11-05| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-12-22| B06A| Patent application procedure suspended [chapter 6.1 patent gazette]|
    2021-03-02| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2021-05-25| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 23/08/2012, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US13/220,087|US10227857B2|2011-08-29|2011-08-29|Modeling and simulation of complete drill strings|
    US13/220,087|2011-08-29|
    PCT/US2012/052082|WO2013032863A1|2011-08-29|2012-08-23|Modeling and simulation of complete drill strings|
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