巴西专利BR112012006391B1 METHODS FOR DRILLING A SURFACE HOLE IN A TERRESTRIAL FORMATION AND TO MAINTAIN NON-STATIONARY STATE

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专利摘要:
methods for drilling a drillhole in a ground formation and for maintaining non-steady state conditions in a drillhole, and, computer readable storage media. A method for drilling a borehole in a ground formation is described which comprises (a) providing a drilling system including a drilling column with a longitudinal axis, a wellbore assembly coupled to a lower end of the drilling column, and a drill bit coupled to a lower end of the wellbore assembly. further, the method comprises (b) rotating the drill bit at a rotational speed. Additionally, the method comprises (c) applying weight over the drill bit to the drill bit and advancing the drill bit through the formation to form the borehole. still further, the method comprises (d) pumping a drilling fluid down the drill string to the drill bit. The drilling fluid has a lower flow rate in the drilling column. furthermore, the method comprises (e) oscillating the rotational speed of the drill bit during (c). The method also comprises (f) generating non-steady state conditions at the drillhole during (e).
公开号:BR112012006391B1
申请号:R112012006391-0
申请日:2010-09-21
公开日:2019-05-28
发明作者:Robert Eugene MEBANE；Frederick Ray Florence
申请人:National Oilwell Varco, L.P.；
IPC主号:

专利说明:

“METHODS FOR DRILLING A DRILLING HOLE IN A TERRESTRIAL FORMATION AND FOR MAINTAINING NON-STATIONARY STATE CONDITIONS IN A DRILLING HOLE, AND, COMPUTER-READABLE STORAGE MEDIA” FUNDAMENTALS OF THE INVENTION
Field of the invention [001] The disclosure relates in general to methods and systems for drilling boreholes for the final recovery of oil, gas or minerals. More particularly, the disclosure concerns methods and systems to prevent, interrupt and / or preemptively prevent steady-state conditions and undesirable harmonic movements during drilling operations.
Technology Basics [002] To obtain hydrocarbons such as oil and gas, drillholes are drilled by turning a drill bit attached to a drill string. The drill bit is typically mounted on the lower end of the drill string as part of a downhole assembly (BHA) and is rotated by rotating the drill string on the surface or by the actuation of engines or subsurface turbines, or both the methods. With weight applied to the drill string, the rotary drill bit fits the ground formation and continues to form a borehole along a path towards a target zone.
[003] To assist in the removal of drilling chips from the bottom of the borehole, pressurized drilling fluid (commonly known as mud or drilling fluid) is pumped down the drilling column to the drill bit mounted on the bottom end of the assembly rock bottom. The drilling fluid exits the drill bit through nozzles or jet assemblies positioned in holes formed in the drill bit body. To efficiently remove chips from the
Petition 870190014537, of 12/02/2019, p. 10/119 / 35 drilling, the drilling fluid must carry the chips radially outward at the bottom of the borehole, and then upward through the annular crown
X between the drill string and the borehole wall. As the drilling fluid seeps past the cutting structure, the fluid collides at the bottom of the borehole and spreads radially out of the annular crown. In general, as the cutting removal efficiency is increased, the cutting efficiency and associated penetration rate (ROP) of the drill bit are also increased.
[004] Numerous subsurface devices placed in close proximity to the drill bit measure certain subsurface parameters associated with drilling and subsurface conditions. Such devices typically include sensors for measuring subsurface temperatures and pressures, azimuth and inclination measurement devices, and a resistivity measurement device for determining the presence of hydrocarbons and water. Additional subsurface instruments, known as profiling tools during drilling (LWD) and / or measurement during drilling (MWD), are often attached to the drill string to determine formation geology and formation fluid conditions during drilling operations. The information provided to the operator during drilling typically includes drilling parameters, such as weight on the drill bit (WOB), rotational speed of the drill bit and / or drill string, and the flow rate of the drilling fluid. In some cases, the drilling operator is also provided with selected information from subsurface sensors such as location and direction of travel of the drill bit, subsurface pressure, and possibly formation parameters such as resistivity and porosity.
[005] Drill holes are usually drilled along predetermined paths and the drilling of a typical drill hole if
Petition 870190014537, of 12/02/2019, p. 11/119 / 35 gives through several formations. Subsurface operating conditions can change and the operator must react to such changes and adjust the controlled parameters of the surface to optimize drilling operations. Drilling parameters typically controlled by the drilling operator to optimize drilling operations include the weight on the drill bit (WOB), flow of drilling fluid through the drill string (flow rate and pressure), the rotational speed of the drill. drilling column, axial position of the drilling column and the drill bit inside the borehole, and the density and viscosity of the drilling fluid. During most conventional drilling operations, the drilling operator adjusts the various drilling parameters controlled on the surface in response to the detection of certain subsurface conditions, or after it.
[006] In general, the drill string, drill bit and drilling fluid each feed energy into the drilling process. Namely, rotation of the drill string and drill bit feeds energy in the drilling process, the axial movement of the drill string and drill bit feeds energy in the drilling process, and the pressure and flow rate of the drilling fluid feed energy in the drilling process. When the input of energy by (a) the rotation of the drill string and drill bit, (b) the flow of drill fluid, (c) the movement of the drill string and drill bit, or (d) the combination from (a) to (c) is uniform and constant over a period of time, it has the potential to create steady-state subsurface conditions and / or unwanted harmonic movements, which can lead to problems such as vibrations due to adhesion- sliding, insufficient hole cleaning, lateral vibration of the drill bit, lateral vibration of the drill string, excessive vibrations (lateral and / or axial), or combinations thereof.
Petition 870190014537, of 12/02/2019, p. 12/119 / 35 [007] As previously described, during most conventional drilling operations, the drilling operator adjusts the various drilling parameters controlled on the surface in response to the detection of certain undesirable subsurface conditions, or after this detection. Typically, the drilling operator monitors subsurface conditions, tries to identify the occurrence of undesirable subsurface conditions, and then takes actions on the surface, adjusting one or more of the controlled drilling parameters on the surface, to stop the condition (s) ) of undesirable subsurface (s). In this way, this conventional approach seeks to manually address subsurface problems after they arise. In some cases, by the time the drilling operator recognizes the subsurface problem and changes the controlled drilling parameters on the surface, damage to the drill string, drill bit and / or other subsurface components has already occurred.
[008] Some drilling operations employ predictive models that receive data relating to surface and / or subsurface conditions and produce a set of recommended values for drilling parameters (for example, drill bit RPM) based on analysis of such measurements. The recommended drilling parameters can be implemented manually or via an automatic control system. However, the physics behind such modeling schemes is complex, and typically depends on accurate surface measurements and subsurface conditions, which are often difficult to obtain in the aggressive drilling environment. Consequently, some of the predictive models are less effective than desired.
[009] Thus, there is a need in the art for drilling systems and methods that overcome the problems associated with prior art systems. Such drilling systems and methods would be particularly well accepted if they offer the potential for
Petition 870190014537, of 12/02/2019, p. 13/119 / 35 proactively interrupt or avoid steady state conditions and undesirable harmonic subsurface movements.
SUMMARY OF REVELATION [0010] These and other needs in the art are addressed in a modality by a method for drilling a borehole in a land formation. In one embodiment, the method comprises (a) providing a drilling system including a drilling column with a longitudinal axis, a downhole assembly attached to a lower end of the drilling column and a drill bit attached to a lower end of the downhole set. Furthermore, the method comprises (b) rotating the drill bit at rotational speed. Additionally, the method comprises (c) applying weight on the drill bit to the drill bit and advancing the drill bit through the formation to form the borehole. In addition, the method further comprises (d) pumping a drilling fluid down the drilling column to the drill bit. The drilling fluid has a lower flow rate in the drilling column. In addition, the method comprises (e) oscillating the rotational speed of the drill bit during (c). The method also comprises (f) generating non-steady-state conditions in the borehole during (e).
[0011] These and other needs in the art are addressed in another modality by a method for maintaining non-stationary state conditions in a borehole being drilled in a land formation. In one embodiment, the method comprises (a) providing a drilling system including a drilling column with a longitudinal axis, a downhole assembly attached to a lower end of the drilling column, and a drill bit attached to one end bottom of the downhole assembly. Furthermore, the method comprises (b) applying torque to the drill bit to rotate the drill bit
Petition 870190014537, of 12/02/2019, p. 11/149 / 35 drilling. The drill bit has a rotational speed and a rotational acceleration. Additionally, the method comprises (c) applying weight on the drill bit to the drill bit to advance the drill bit through the formation to form the borehole. The drill bit has an axial speed and an axial acceleration. In addition, the method further comprises (d) pumping a drilling fluid down the drilling column to the drill bit. The drilling fluid has a flow rate below the drill string and a pressure at an inlet of the drill string. The rotational speed of the drill bit, the rotational acceleration of the drill bit, the axial speed of the drill bit, the axial acceleration of the drill bit, the flow rate of the drilling fluid below in the drill column and the fluid pressure drilling holes at the entrance of the drilling column are each a drilling parameter. In addition, the method comprises (e) controllably oscillating two or more of the following drilling parameters during (c): the rotational speed of the drill bit; the rotational acceleration of the drill bit; the axial speed of the drill bit; the axial acceleration of the drill bit; the flow rate of the drilling fluid below in the drilling column; and the pressure of the drilling fluid at the inlet of the drilling column.
[0012] These and other needs in the art are addressed in another way by a computer-readable storage medium. In one embodiment, the computer-readable storage media comprises software that, when run by a processor, causes the processor (a) to receive a predetermined maximum rotational speed for a drill string, a predetermined minimum rotational speed for the drill string, and a predetermined set point for the rotational speed of the drill bit. Furthermore, the software, when run by the processor, makes the processor (b)
Petition 870190014537, of 12/02/2019, p. 11/15/35 monitor the rotational speed of the drill string. Additionally, the software, when run by the processor, makes the processor (c) control the rotational speed of the drill string. In addition, the software, when executed by the processor, makes the processor (d) oscillate the rotational speed of the drilling column around the predetermined setpoint for the rotational speed and between the maximum predetermined rotational speed and the minimum predetermined rotational speed . [0013] Thus, modalities described herein comprise a combination of features and advantages designed to address various drawbacks associated with certain devices, systems and methods of the prior art. The various features previously described, as well as other resources, will be apparent to those skilled in the art by reading the following detailed description and by referring to the attached drawings. BRIEF DESCRIPTION OF THE DRAWINGS [0014] For a detailed description of the preferred embodiments of the invention, reference will now be made to the accompanying drawings, in which:
Figure 1 is a schematic view of an embodiment of a drilling system in accordance with the principles described here;
Figure 2 is a schematic of an embodiment of a method for drilling according to the principles described herein;
Figure 3 is a graphical illustration of the oscillation of the rotational speed of a drill string over time;
Figure 4 is a graphic illustration of the oscillation of the rotational speed of a drill string over time;
Figure 5 is a graphical illustration of the oscillation of the axial speed of a drill string and drill bit over time;
Figure 6 is a graphical illustration of the oscillation of the drilling fluid flow rate with time;
Petition 870190014537, of 12/02/2019, p. 11/16/35
Figure 7 is a graphical illustration of the oscillation, over time, of the total subsurface energy input through the rotation of the drill string and drill bit, the axial movement of the drill string and drill bit, and the flow of drilling mud; and
Figure 8 is a graphical illustration of the oscillation, over time, of the total subsurface energy input through the rotation of the drill string and drill bit, the axial movement of the drill string and drill bit, and the flow of drilling mud. DESCRIPTION OF THE REVEALED MODALITIES [0015] The following discussion is concerned with various modalities of the invention. Although one or more of these modalities may be preferred, the disclosed modalities should not be interpreted, or otherwise used, as limiting the scope of the disclosure, including the claims. Furthermore, those skilled in the art will understand that the following description has a broad application, and the discussion of any modality should only be exemplary of that modality, and is not intended to imply that the scope of the disclosure, including the claims, is limited to that modality.
[0016] Certain terms are used in the following description and claims to refer to particular features or components. As those skilled in the art will realize, different people can refer to the same resource or component by different names. This document is not intended to differentiate components or features that differ in name, but not in function. The figures in the drawings are not necessarily to scale. Certain features and components here may be shown on an enlarged scale or in a somewhat schematic form and some details of conventional elements may not be shown for the sake of clarity and conciseness.
[0017] In the following discussion and in the claims, the terms including and comprising are used in a generic manner and should therefore be interpreted to mean including, but not
Petition 870190014537, of 12/02/2019, p. 17/119 / 35 limitations. Also, the term coupling or coupling must mean both an indirect and a direct connection. Thus, if a first device couples to a second device, that connection can be through a direct connection, or through an indirect connection via other devices and connections. In addition, the terms axially and axially in general mean along or parallel to a central or longitudinal axis (for example, the axis of the drill string), while the terms radially and radially in general mean perpendicular to the central or longitudinal axis. For example, an axial distance refers to a distance measured along or parallel to the central or longitudinal axis, and a radial distance refers to a distance measured perpendicularly to the central or longitudinal axis.
[0018] Referring now to figure 1, a schematic diagram of a modality of a drilling system 10 is shown according to the principles described here. The drilling system 10 includes a drilling set 90 for drilling a borehole 26. Furthermore, the drilling system 10 includes a drilling tower 11 with a floor 12, which supports a rotary table 14 which is rotated by a driving machine such as an electric motor (not shown) at a desired rotational speed and controlled by a motor controller (not shown). The motor controller can be a silicon controlled rectifier (SCR) system, a Variable Frequency Device (VFD), or another type of suitable controller. In other embodiments, the rotary table (for example, rotary table 14) can be increased or replaced by a system for rotating the top of the column suspended in the drilling tower (for example, drilling tower 11) and connected to the drilling column ( for example, drill column 20).
[0019] Drill assembly 90 comprises a drill column 20 including a drill column 22 extending to
Petition 870190014537, of 12/02/2019, p. 18/119 / 35 under the rotary table 14 through a pressure control device 15 inside the borehole 26. The pressure control device 15 is normally hydraulically operated and can contain sensors to detect certain operational parameters and control the actuation of the pressure control device 15. A drill bit 50, attached to the lower end of the drill column 20, disintegrates the land formations when it is rotated with weight on the drill bit (WOB) to drill the borehole 26 The drill string 20 is coupled to a main winch 30 via a kelly joint 21, swivel 28 and line 29 through a pulley. During drilling operations, the main winch 30 is operated to control the WOB, which gives the drill bit penetration rate 50 through the formation. In this embodiment, the drill bit 50 can be rotated from the surface by the drill column 20 via the rotary table 14 and / or a column top rotation system, rotated by the subsurface mud motor 55 arranged in the drill set 90, or combinations thereof (for example, rotated both by the rotary table 14 via the drilling column 20 and by the mud motor 55, rotated by a top column rotation system and the mud motor 55, etc.). For example, rotation via subsurface motor 55 can be used to supplement the rotational power of the rotary table 14, if necessary, and / or to make changes to the drilling process. In any case, the penetration rate (ROP) of the drill bit 50 in the borehole 26 for a given formation and a drill set largely depends on the weight on the drill bit and the rotational speed of the drill bit.
[0020] During drilling operations, a suitable drilling fluid 31 is pumped under pressure from a mud tank 32 through the drilling column 20 by a mud pump 34. Drilling fluid 31 passes from the mud pump 34 to the column drill 20 via a shock absorber
Petition 870190014537, of 12/02/2019, p. 19/119 / 35 suction 36, fluid line 38 and kelly joint 21. Drilling fluid 31 is discharged at the bottom of the borehole through nozzles on the face of the drill bit 50, circulates to the surface through an annular space 27 radially positioned between the drilling column 20 and the side wall of the borehole 26, and then returns to the mud tank 32 via a solids control system 36 and a return line 35. The solids control system 36 may include any suitable solid control equipment known in the art including, without limitation, oscillating screens, centrifuges, and automatic chemical additive systems. The control system 36 can include sensors and automatic controls to monitor and control, respectively, various operational parameters such as centrifugal rpm. It should be noted that most of the surface equipment for handling the drilling fluid is application specific and may vary from case to case.
[0021] Various sensors are employed in drilling system 10 to monitor a variety of drilling parameters controlled on the surface and subsurface conditions. For example, S1 sensors in line 38 measure and provide information regarding the flow rate and pressure of the drilling fluid. In addition, a surface torque sensor S2 measures and provides information about the torque applied to the drilling column 20 on the surface, and a subsurface torque sensor S5 measures and provides information about the torque applied to the drilling bit 50 Although the torque sensor S2 is used in this modality to measure the torque applied to the surface, in other modalities, the applied torque can also be calculated based on measurements of the applied power in the rotation system of the top of the column or rotary table to rotate. the drill column. A speed and rotational acceleration sensor S3 measures and provides information about the speed and rotational acceleration of drill column 20 and drill bit 50. Additionally, an S4 sensor
Petition 870190014537, of 12/02/2019, p. 20/119 / 35 measures and provides information regarding the circumferential load of drilling column 20 and WOB applied to drilling bit 50. The speed and axial acceleration of drilling column 20 and drilling bit 50 are measured and provided by an encoder or position sensor S6 associated with the main winch rotating drum 30. The axial acceleration of the drill string and drill bit can also be measured with an accelerometer attached to the drill string or one of the tools on the drill string, such as a MWD or LWD tool, and the axial speed can be computed based on the measurements of axial acceleration. Additional sensors are associated with the motor drive system to monitor the operation of the drive system. These include, but are not limited to, sensors to detect motor speed (RPM), winding voltage, winding resistance, motor current and motor temperature. In addition, in addition, other sensors are used to measure and provide information relating to solids control equipment, and pressure control equipment (for example, to indicate the status of the hydraulic system and operational pressures of the wellhead safety system, and shock absorber associated with pressure control device 15). [0022] Signals from the various sensors (for example, Si, S2, S3,
S4, S5, Only, etc.) are powered by a control system processor 60 located in the tool pusher cabin 47 or in the operator cabin 46. In general, the processor (for example, processor 60) can be any device or system suitable for carrying out programmed instructions including, without limitation, general purpose processors, digital signal processors and microcontrollers configured to carry out instructions provided by software programming. Processor architectures in general include execution units (for example, fixed point, floating point, integer, etc.), storage (for example, records, memory, etc.), instruction decoding, peripherals (for example,
Petition 870190014537, of 12/02/2019, p. 21/119 / 35 interrupt controllers, timers, direct memory access controllers, etc.), input / output systems and devices (eg, serial ports, parallel ports, etc.), and various other components and subsystems. Software programming can be stored on computer-readable media. Exemplary computer-readable media include semiconductor memory, optical storage and magnetic storage.
[0023] Referring further to figure 1, processor 60 is operationally coupled with main winches 30 and other mechanical, hydraulic, pneumatic, electronic and wireless subsystems of drilling system 10 to control various drilling parameters. In particular, based on the input of the various sensors, processor 60 can automatically adjust drilling parameters including, without limitation, the weight on the drill bit applied to the drill bit 50; the torque applied to the drill column 20 and drill bit 50 (via rotary table 14, a top column rotation system, mud engine 55, or combinations thereof); the speed and rotational acceleration of the drill string 20 and the drill bit 50; the axial position, speed and acceleration of the drill string 20 and drill bit 50; and the drilling fluid pressure and flow rate 31 flowing down the drilling column 20 to the drill bit 50.
[0024] Furthermore, processor 60 allows feeding a predetermined maximum and minimum value for each drilling parameter including, without limitation, a predetermined maximum and minimum torque applied to the drilling column and drill bit; a predetermined maximum and minimum rotational speed for the drill string and drill bit; a predetermined maximum and minimum acceleration for the drill string and drill bit; a predetermined maximum and minimum axial speed for the drill string and drill bit;
Petition 870190014537, of 12/02/2019, p. 22/119 / 35 a predetermined maximum and minimum acceleration for the drill string and drill bit; a predetermined maximum and minimum flow rate for the drilling fluid; and a predetermined maximum and minimum pressure for the drilling fluid. In this modality, the entry of the desired maximum and minimum predetermined value for each drilling parameter is performed via monitors 49. However, in other modalities, other suitable devices can be used to communicate the desired maximum and minimum predetermined for each drilling parameter including, without limitation, wireless communications, a keyboard, a mouse, or combinations thereof. In addition, the predetermined maximum and minimum desired drilling parameters can be fed from the platform or from a remote location. As an alternative to predetermined minimum and maximum user input values for each drilling parameter, processor 60 can dynamically calculate or determine minimum and maximum values for each drilling parameter based on measurements as drilling progresses.
[0025] Processor 60 also receives and interprets signals from the various sensors on the platform, from subsurface sensors and other input data from service contractors, and sends the received and interpreted data to the operator via monitors 49. Based on a comparison of data measured with the well plan models, and a comparison of the measured data with the minimum and maximum values for each drilling parameter, processor 60 determines whether any adjustment is required to maintain the current well plan, and displays status information or alert via monitors 49. Thus, in this mode, monitors 49 allow the user interface to both enter and exit with information. Multiple display screens (for example, monitors 49), representing various platform operations, may be available for user calls.
Petition 870190014537, of 12/02/2019, p. 23/119 / 35 [0026] Based on a comparison of the measured data with the well planning models and the minimum and maximum values for the drilling parameters, processor 60 can (a) suggest the appropriate corrective action and request authorization to implement such corrective action, or (b) automatically implement the appropriate corrective action, thereby minimizing potential delays by relying on manual adjustment of surface-controlled drilling parameters. Measured data and status information can also be communicated using wired or wireless techniques 48 to remote locations at the well site. Processor 60 is preferably configured and adapted to execute software instructions that allow processor 60 to implement drilling method 200 described in more detail below with respect to figure 2.
[0027] In this modality, drilling set 90 also includes a MWD and / or LWD 56 set containing sensors to determine drilling dynamics, directional and formation parameters and subsurface conditions. In this mode, the detected values are transmitted to the surface via mud pulse telemetry and received by a sensor 43 mounted in line 38. The pressure pulses are detected by the circuit system at the receiver 40 and the data processed by a receiver processor 44. Although mud pulse telemetry is employed in this modality, in general, any suitable telemetry scheme can be employed to communicate data from subsurface sensors to the surface including, without limitation, electromagnetic telemetry, acoustic telemetry, or physical connections (eg example, drill string connected by wires).
[0028] Although in figure 1 a terrestrial platform is generally drawn, modalities disclosed here are also equally applicable to offshore drilling systems and methods. Additionally, several components of the drilling system 10 can be automated in several
Petition 870190014537, of 12/02/2019, p. 24/119 / 35 degrees like, for example, using a rotation system from the top of the column, instead of a kelly.
[0029] Referring now to figure 2, a modality of a drilling method 200 according to the principles described herein is schematically shown. The drilling method 200 is implemented by the previously described drilling system 10. In general, drilling method 200 includes steps to vary (continuously or periodically) and / or oscillate energy input into the drilling process to improve drilling efficiency, and to interrupt, mitigate and / or preemptively prevent steady state conditions from subsurface and associated problems such as vibrations due to the adhesion-slip effect, hole cleaning problems, lateral vibration of the drill bit, lateral vibration of the drilling column and excessive lateral or axial vibrations. In general, energy is fed into the drilling system by (a) the rotation of the drill string and drill bit, (b) the axial movement of the drill string and drill bit, and (c) the flow of drilling fluid . However, as will be described in more detail below, drilling method 200 introduces energy variations and fluctuations in the drilling process via controlled manipulation of drilling parameters including, without limitation, the applied torque, speed and rotational acceleration of the drilling column. and drill bit; the speed and axial acceleration of the drill string and drill bit; and the drilling fluid pressure and flow rate. Controlled manipulation of drilling parameters can be done manually by the drilling operator, but is preferably automated via a drilling software application similar to DrillLink / CyberLink available from National Oilwell Varco, LP in Houston, Texas and associated drilling system such as system 10 previously described.
Petition 870190014537, of 12/02/2019, p. 25/119 / 35 [0030] To start or start method 200, the well plane model, the predetermined set point (s) for each drilling parameter (for example, torque, speed and rotational acceleration applied to the drill string and drill bit; the axial speed and acceleration of the drill string and drill bit; and the drilling mud flow rate and pressure), and the predetermined minimum and maximum values for each drilling parameter are fed into the drilling system in block 205. For example, in the previously described drilling system 10, the well plane model, set points and predetermined minimum and maximum values for each drilling parameter are fed into the processor 60 via monitor 49 or another suitable input mechanism. Then, at block 210, drilling operations begin by applying torque to rotate the drill bit (for example, drill bit 50), pumping pressurized drilling fluid (for example, fluid 31) down the drill column (for example, drill column 20), applying weight to the drill bit and advancing the drill column and drill bit through the land formation to form a borehole (for example, borehole 26). As previously described, the drill bit can be rotated by the drill column via the rotary table, top column rotation system, by subsurface mud engines, or combinations thereof.
[0031] During drilling, subsurface drilling conditions and drilling parameters are continuously measured and monitored in block 215. The various sensors in the borehole assembly of the drilling system can measure subsurface conditions such as temperature, pressure , vibrations, formation characteristics, etc. Subsurface sensors can also be used to measure drilling parameters such as axial position, drill bit speed and acceleration, and the
Petition 870190014537, of 12/02/2019, p. 26/119 / 35 applied torque, speed and rotational acceleration of the drill bit. In addition, several sensors on the surface can measure drilling parameters such as mud pump speed, drilling fluid pressure and flow rate, column top rotation system speed and acceleration, applied torque, rotational speed, and acceleration of the drill string and drill bit, and axial speed and acceleration of the drill string and drill bit. For example, in the previously described drilling system 10, the various sensors (for example, sensors S1, S2, S3, S4, S5, Only, etc.) measure subsurface drilling conditions and the drilling parameters, the measured data are communicated to processor 60, and processor 60 tracks and monitors the measured data.
[0032] Now going to block 216, the measured and collected data related to subsurface conditions and drilling parameters are compared with the well plan model, the set points and the maximum and minimum values for each drilling parameter . For example, in the previously described drilling system 10, each actual measured drilling parameter (for example, rotational speed of the drill bit 50) is compared with its corresponding setpoint, and the predetermined minimum and maximum values (for example, point setting and predetermined minimum and maximum values for rotational speed of the drill bit) by processor 60. One purpose of this comparison is to ensure that each drilling parameter is kept between its corresponding maximum and minimum predetermined values. For example, if the actual measured drilling parameter exceeds the maximum predetermined value or falls below the minimum predetermined value, processor 60 will notify the operator and / or automatically instruct the appropriate subsystems within drilling system 10 to adjust the drilling parameter for such that it falls between its corresponding maximum and minimum predetermined values.
Petition 870190014537, of 12/02/2019, p. 27/119 / 35 [0033] Referring also to figure 2, the measured and collected data related to subsurface conditions and drilling parameters are also used to predict and / or identify undesirable steady-state conditions and associated problems accordingly with block 218. For example, when the drill bit is rotated by the drill string, the actual rotational speed measured from the drill string on the surface that is relatively constant and the actual measured rotational speed of the drill bit that is changing (this is, not constant) is evidence of possible vibrations due to the stick-slip effect as the drill bit or downhole assembly turns on in the formation, its rotational speed decreases, and the torsion accumulates in the tube. Consequently, an unexpected increase in the applied torque can also be detected and indicate conditions of vibrations by the effect of subsurface slip adhesion.
[0034] Now going to blocks 220, 230, 24, during drilling, one or more drilling parameters are oscillated to create or maintain non-steady-state drilling conditions by varying the energy input in the drilling process accordingly with block 250. In the form used here, the terms oscillate and oscillate refer to the repeated increase and decrease in the value of a drilling parameter or energy input into the drilling system over time. It should be noted that these oscillations in one or more drilling parameters are intentional and controlled oscillations, which can be done manually by the drill through surface control systems or performed automatically by a processor (eg processor 60) and associated software able to manipulate control systems on the surface. As will be described in more detail below, the oscillations of one or more drilling parameters according to steps 220, 230, 240, and the oscillation of the energy input in the drilling process according to step 250 are preferably in
Petition 870190014537, of 12/02/2019, p. 11/28/35 around the corresponding set points (that is, above and below the corresponding set points), between the corresponding maximum and minimum predetermined values, and random (that is, random frequencies and amplitudes) to avoid resonance conditions potential. In addition, the oscillation periods are preferably relatively small (for example, less than 10 seconds).
[0035] In block 220, the applied torque, the resulting rotational speed (for example, RPM) and the resulting rotational acceleration of the drill string and drill bit are controllably varied and oscillated over time. Such adjustments are preferably made continuously or relatively frequently (for example, in a few seconds), thus resulting in the oscillation of the applied torque, speed and rotational acceleration of the drill string and drill bit over time. As previously described, the terms oscillate and oscillate refer to the repeated increase and decrease in the value of a drilling parameter (or energy input into the drilling system) over time. Thus, for example, oscillation in the rotational speed of a drill bit refers to the repeated increase and decrease in the rotational speed of the drill bit over time. It should be noted that the torque applied to the drill string impacts the speed and rotational acceleration of the drill string and drill bit. However, the torque applied to the drill bit by the subsurface mud engine impacts the speed and rotational acceleration of the drill bit, but not the speed or rotational acceleration of the drill string.
[0036] The period and amplitude of the oscillations in each of the applied torque, speed and rotational acceleration can be random or non-random over time, but are preferably controlled and managed to (a) oscillate around one or more points of predetermined settings for the applied torque, speed and rotational acceleration,
Petition 870190014537, of 12/02/2019, p. 29/119 / 35 respectively (that is, each cycle moves above and below the predetermined setpoint over time), and (b) staying between one or more predetermined maximum and minimum applied torques, rotational speeds and rotational accelerations, respectively, prescribed by the well plan for the particular well being drilled. In addition, the periods of oscillations in applied torque, speed and rotational acceleration are preferably less than one minute, more preferably less than 10 seconds and even more preferably less than 5 seconds. For example, in figure 3, the oscillation of the rotational speed 300 of an exemplary drill bit (for example, drill bit 50) over time is shown graphically. In this embodiment, the rotational speed 300 of the drill bit is oscillated with time in general around a setpoint of the predetermined rotational speed 301. In other words, the rotational speed 300 repeatedly moves above and below the setpoint 301 with the time. In addition, the rotational speed 300 of the drill bit is maintained within a predetermined range R300 defined by a predetermined upper or maximum rotational speed 302 and a predetermined lower or minimum rotational speed 303. As another example, in Figure 4, the oscillation of the rotational speed 300 of the drill bit over time is shown graphically. The rotational speed 300 of the drill bit is maintained within the predetermined range R300 defined by the predetermined upper and lower rotational speeds 302, 303, respectively, as previously described. However, in figure 4, there are multiple set points of the predetermined rotational speed 301a, 301b, 301c, 301d, around which the rotational speed 300 oscillates in different time segments. In the modalities shown in figures 3 and 4, the amplitude and period of oscillations of rotational speed 300 vary randomly with time, and oscillations in rotational speed 300 are generally sinusoidal.
Petition 870190014537, of 12/02/2019, p. 11/30/35
However, in general, the amplitude of each of the applied torque, speed and rotational acceleration oscillations, the periods of each of the applied torque, speed and rotational acceleration oscillations, or both, can be random, uniform or constant over time . Additionally, in general, the oscillations in the applied torque, speed and rotational acceleration can be trapezoidal, triangular, rectangular, sinusoidal, or combinations of these.
[0037] Without being limited by this or any particular theory, all other conditions being constant, the oscillations in the applied torque, speed and rotational acceleration of the drilling column and the drill bit result in the oscillation of the energy input in the drilling process through the drill string and drill bit. Additionally, without being limited to this or any particular theory, the oscillation of the energy input through the drill string and drill bit is directly related to the oscillation of the applied torque, speed and rotational acceleration of the drill string and drill bit. Thus, when the absolute value of any one or more of the applied torque, speed and rotational acceleration of the drill string and drill bit increases, the associated energy input in the drilling process increases. Due to the oscillation of the applied torque, speed and rotational acceleration of the drill string and drill bit, and consequently oscillation of the energy input in the drilling process by the drill string and drill bit, modalities described here offer the potential to proactively interrupt, mitigate and / or preemptively prevent the formation of steady-state subsurface conditions and undesirable harmonic movements, and associated problems.
[0038] Referring again to figure 2, in block 230, the axial speed and axial acceleration of the drill string and drill bit are controllably varied and oscillated over time. Such adjustments are
Petition 870190014537, of 12/02/2019, p. 31/119 / 35 preferably performed continuously or relatively frequently over time (for example, in a few seconds), thus resulting in the oscillation of the speed and axial acceleration of the drill string and drill bit over time. It should be noted that the drill bit is coupled to the lower end of the drill string and thus the axial position of the drill bit is affected by changes in the axial position in the drill string. As previously described, the terms oscillate and oscillate refer to the repeated increase and decrease in the value of a drilling parameter (or energy input into the drilling system) over time. Thus, for example, oscillation in the axial speed of a drill bit refers to the repeated increase and decrease in the axial speed of the drill bit over time.
[0039] The period and amplitude of the oscillations in each of the speed and axial acceleration can be random or nonrandom over time, but are preferably controlled and managed to (a) oscillate around one or more predetermined set points for the axial speed and acceleration, respectively (that is, each one moves cyclically above and below a predetermined setpoint over time), and (b) staying between one or more axial and maximum and minimum and predetermined acceleration speeds, respectively , prescribed by the well plan for the particular well being drilled. In addition, the periods of oscillations in speed and axial acceleration are preferably less than one minute, more preferably less than 10 seconds, and even more preferably less than 5 seconds. For example, in figure 5, the oscillation of the axial speed 400 of the drill string is shown graphically. In this embodiment, the axial speed 400 of the drill string is oscillated with time in general around a predetermined setpoint 401 for axial speed 400. In other words, axial speed 400 moves repeatedly above and below the point in
Petition 870190014537, of 12/02/2019, p. 32/119 / 35 adjust 401 over time. Furthermore, axial speed 400 is maintained within a predetermined range R400 defined by a predetermined upper or maximum axial speed 402 and a predetermined lower or minimum axial speed 403. In this embodiment, the amplitude and period of oscillations of axial speed 400 vary randomly over time, and oscillations in axial velocity 400 are generally rectangular. However, in general, the amplitude of the speed and axial acceleration oscillations, the periods of each of the speed and axial acceleration oscillations, or both, can be random, uniform, or constant over time. Additionally, in general, oscillations in oscillations in speed and axial acceleration can be trapezoidal, triangular, rectangular, sinusoidal, or combinations of these. [0040] Without being limited by this or any particular theory, all other conditions being constant, the oscillations in the speed and axial acceleration of the drilling column and the drill bit result in the oscillation of the energy input in the drilling process through the column of drilling and drill bit. Additionally, without being limited by this or any particular theory, the oscillation of the energy input by the axial movement of the drill string and drill bit is directly related to the oscillation in the speed and axial acceleration of the drill string and drill bit. Thus, when the absolute value of one or both of the speed and axial acceleration of the drill string and drill bit increases, the associated energy input in the drilling process increases. By oscillating the speed and axial acceleration of the drill string and drill bit, and consequently oscillating the energy input in the drilling process through the drill string and drill bit, modalities described here offer the potential to proactively interrupt, attenuate and / or preemptively prevent the formation of steady-state subsurface conditions and undesirable harmonic movements, and associated problems.
Petition 870190014537, of 12/02/2019, p. 33/119 / 35 [0041] Referring again to figure 2, in block 240, the pressure and flow rate of the drilling fluid are controllably varied and oscillated with time. Such adjustments to the drilling fluid flow rate and pressure are preferably carried out continuously or relatively frequently over time (for example, in a few seconds), thus resulting in the drilling fluid flow rate and pressure fluctuating over time. . In this mode, the pressure and flow rate of the drilling fluid are adjusted by increasing and decreasing the strokes of the mud pumps per minute. In addition, fluctuations in the flow rate and / or pressure of the drilling mud can be achieved by strangling and releasing one or more mud pumps on the surface repeatedly. It should be noted that, in modalities that employ subsurface mud engines to rotate the drill bit, oscillations in the rate of flow and pressure of the drilling fluid will result in rotational oscillations in the speed of the mud engine and, consequently, oscillations in the speed of cutting the drill bit. As previously described, the terms oscillate and oscillate refer to the repeated increase and decrease in the value of a drilling parameter (or energy input into the drilling system) over time. Thus, for example, fluctuation in the drilling mud flow rate refers to the repeated increase and decrease in the drilling mud flow rate over time.
[0042] The period and amplitude of the oscillations in each of the pressure and flow rate of the drilling fluid can be random or non-random over time, but are preferably controlled and managed to (a) oscillate around one or more points predetermined set points for pressure and flow rate, respectively (that is, each cyclically moves above and below a predetermined set point over time), and (b) staying between one or more pressure and maximum flow rate and predetermined minimum, respectively, as prescribed by the well plan for the
Petition 870190014537, of 12/02/2019, p. 34/119 / 35 private well being drilled. In addition, the periods of oscillations in speed and axial acceleration are preferably less than one minute, more preferably less than 10 seconds and even more preferably less than 5 seconds. For example, in figure 6, the variation in the flow rate of drilling fluid 500 is shown graphically. In this embodiment, the flow rate of the drilling fluid 500 is oscillated with time in general around a predetermined setpoint 501 for the flow rate 500. In other words, the flow rate 500 repeatedly moves up and below setpoint 301 over time. Furthermore, the flow rate 500 is kept within a predetermined range R500 defined by a predetermined upper or maximum flow rate 502 and a predetermined lower or minimum flow rate 503. In this embodiment, the amplitude and period of oscillations of the flow rate 500 varies randomly over time, and fluctuations in flow rate 500 are generally trapezoidal. However, in general, the amplitude of each of the flow rate and drilling pressure oscillations, the periods of each of the flow rate and drilling pressure oscillations, or both, can be random, uniform or constant over time. . In addition, in general, fluctuations in flow rate and pressure can be trapezoidal, triangular, rectangular, sinusoidal, or combinations of these.
[0043] Without being limited by this or any particular theory, all other conditions being constant, oscillations in the rate of flow and pressure of the drilling fluid result in the oscillation of the energy input in the drilling process by the drilling fluid. Additionally, without being limited by this or any particular theory, oscillations in the energy input through the drilling fluid are directly related to the oscillations in the flow rate and pressure of the drilling fluid. Thus, when the drilling fluid flow rate and pressure increase, the associated energy input into the drilling process by the drilling fluid
Petition 870190014537, of 12/02/2019, p. 35/119 / 35 increases. Due to the oscillation of the drilling fluid flow rate and pressure and, consequently, oscillation of the energy input in the drilling process by the drilling fluid, modalities described here offer the potential to proactively interrupt, mitigate and / or preemptively prevent the formation of conditions steady-state subsurface and undesirable harmonic movements, and associated problems. For example, fluctuation in the flow rate and pressure of the drilling fluid can interrupt and / or prevent the formation of undesirable eddies in the drilling fluid flow, as well as steady-state movements and sedimentation of the shavings from the formation. Such swirls and steady state movements of the shavings from the formation can prevent the shavings from effectively circulating out of the hole. In this way, oscillation of the drilling fluid flow rate and pressure offers the potential to improve chip removal efficiency.
[0044] In drilling operations employing mud pulse telemetry, the wave geometry representative of oscillations in the drilling fluid flow rate and pressure, the predetermined setpoint for the drilling fluid flow rate and pressure, and the predetermined minimum and maximum values for the flow rate and pressure of the drilling fluid are preferably configured to ensure proper communication of information via mud pulses in the drilling fluid (ie minimal or no interference with mud pulse communications) .
[0045] Referring again to figure 2, in block 220, the applied torque, speed and rotational acceleration of the drilling column and the drill bit are varied over time to vary the associated energy input in the drilling process through the column drill bit and drill bit, thus offering the potential to prevent, interrupt and / or preemptively prevent steady-state subsurface conditions, and associated problems (for example, vibrations due to
Petition 870190014537, of 12/02/2019, p. 36/119 / 35 adhesion-slip, hole cleaning deficiency, etc.). Furthermore, in block 230, the speed and axial acceleration of the drill string and drill bit are varied over time to vary the associated energy input in the drilling process by the drill string and drill bit, thus also offering the potential to prevent, interrupt and / or preemptively prevent steady-state subsurface conditions, and associated problems (eg, stick-slip vibrations, hole cleanliness deficiencies, etc.). Finally, at block 240, the pressure and flow rate of the drilling fluid are varied over time to vary the associated energy input into the drilling process by the drilling fluid, thus also offering the potential to prevent, interrupt and / or preemptively prevent steady-state subsurface conditions and associated problems (for example, vibrations due to stick-slip effect, hole cleaning deficiencies, etc.). In general, the oscillation of drilling parameters (for example, the applied torque, speed and rotational acceleration of the drill string and drill bit, the speed and axial acceleration of the drill string and drill bit, and the rate of drilling fluid flow and pressure) can be directly or indirectly controlled by a surface device (eg column top rotation system, block position, mud pumps, etc.), or via a subsurface device (eg mud engine, drilling fluid drift, etc.).
[0046] Going now to block 250, the oscillations in drilling parameters over time according to blocks 220, 230, 240 are intentionally controlled and managed in such a way that the combined effect is the creation or maintenance of drilling conditions of non-steady state subsurface. The non-steady state conditions created in block 250 can be in response to the detection of
Petition 870190014537, of 12/02/2019, p. 37/119 / 35 undesirable steady-state conditions or associated problems (eg, stick-slip vibrations) in step 216, or maintained continuously, or for selected periods of time, thereby preemptively preventing, avoiding and / or interrupting the formation of steady state conditions, and associated problems.
[0047] Referring further to figure 2, the creation or maintenance of non-steady state conditions in block 250 are preferably achieved by varying the total energy input in the drilling process by rotating the drill string and drill bit (ie energy associated with applying torque to the drill string and drill bit, and the rotational speed and acceleration resulting from the drill string and drill bit), the axial movement of the drill string and drill bit drilling (ie, energy associated with the speed and axial acceleration of the drill string and drill bit), and the drilling mud in motion (ie, energy associated with the rate and pressure of the drill mud) with the time. Although torque, rotational speed, rotational acceleration, axial speed, axial acceleration, flow rate and pressure applied are each oscillated in blocks 220, 230, 240, in general, the total energy input in the drilling system by these parameters can be oscillated by oscillating any or more of these drilling parameters, continuously or periodically, over time.
[0048] The period and amplitude of the oscillations in the total energy input in the drilling system by these parameters can be random or nonrandom over time, but are preferably controlled and managed to oscillate around one or more predetermined set points ( that is, move cyclically above and below a predetermined setpoint over time), and (b) remain between one or more predetermined maximum and minimum values, as can be described by
Petition 870190014537, of 12/02/2019, p. 38/119 / 35 well plan for the private well being drilled. In addition, the periods of oscillations in the total energy input in the drilling process by these parameters are preferably less than one minute, more preferably less than 10 seconds and even more preferably less than 5 seconds. For example, in figure 7, the oscillation of the subsurface energy input 600 in the drilling process by rotating the drill string and drill bit, axial movement of the drill string and drill bit, and the drilling mud in movement is shown graphically. In this embodiment, subsurface energy 600 is oscillated with time in general around a predetermined setpoint 601. In other words, subsurface energy 600 moves repeatedly above and below setpoint 601 over time. Furthermore, energy 600 is kept within a predetermined range R600 defined by a predetermined upper or maximum subsurface energy 602 and a predetermined lower or minimum subsurface energy 603. In this embodiment, the amplitudes A1, A2, A3 of the oscillations of subsurface energy varies with time and, in addition, the periods T1, T2, T3 of the subsurface energy oscillations also vary with time. However, in general, the amplitudes of subsurface energy oscillations, the periods of subsurface energy oscillations, or both, can be random, uniform, or constant over time. Additionally, in this modality, the oscillation in the total subsurface energy 600 is generally sinusoidal, however, in general, the oscillations in the total subsurface energy 600 can be triangular, rectangular, sinusoidal, trapezoidal, or combinations thereof. As another example, in figure 8, the total subsurface energy 600 is kept within the predetermined range R600 defined by the predetermined upper and lower total subsurface energy limits 602, 603, respectively. However, in figure 8, there are multiple predetermined set points 601a, 601b,
Petition 870190014537, of 12/02/2019, p. 11/39/35
601c on lathes of which the total subsurface energy 600 fluctuates over time.
[0049] Referring again to figure 2, in block 260, drilling method 200 asks whether drilling should continue. Typically, drilling continues until there is sufficient problem to stop drilling (for example, severe damage to the subsurface component) or the desired depth has been reached. As long as drilling is in progress, process 200 returns to block 210 for oscillation in one or more of the drilling parameters in blocks 220, 230, 240, and the creation or maintenance of non-steady state conditions according to block 250. However, if a decision is made to stop drilling in block 260, drilling operations cease according to block 270. Thus, as long as drilling is in progress, drilling method 200 monitors drilling conditions subsurface and drilling parameters in block 215; compares the subsurface conditions and drilling parameters measured and monitored with the well plan model, set points and corresponding maximum and minimum values for each drilling parameter in block 216; predicts and identifies non-steady-state drilling conditions, and associated problems, in block 218; oscillates the drilling parameters and associated energies in blocks 220, 230, 240; and creates or maintains non-steady state conditions in block 250.
[0050] To allow continuous monitoring of subsurface conditions (eg temperature, vibrations, rotational speeds, axial position, pressure, etc.), the operational parameters of the surface equipment (eg mud pump speed), as well as the control and time management of drilling parameters (applied torque, speed and rotational acceleration of the drill string and drill bit, speed and axial acceleration of the drill string and drill bit, and pressure and flow rate of the drilling fluid), the process
Petition 870190014537, of 12/02/2019, p. 11/40/35
200 is preferably implemented by a semi-automatic or fully automatic drilling system (for example, system 10 previously described) including a drilling software application that allows the entry of predetermined set points and upper and lower limits for each drilling parameter, as well as control of the various drilling systems that allow manipulation of the drilling parameters in the appropriate way. A software solution like this is preferably designed for use by drilling engineers and is located on the platform or remotely via a computer with Internet access. The solution may be an application addition to the DrillLink / CyberLink solution currently offered by National Oilwell Varco, L.P. of Houston, Texas. The solution could be sold or leased. Users could establish operational parameters based on their knowledge of the well plan, in turn they would simply activate the solution and continue their task functions while the system operates.
[0051] Modalities disclosed herein offer the potential to prevent, interrupt and / or preemptively prevent steady-state subsurface conditions and undesirable harmonic behaviors, thereby offering the potential to reduce, minimize and / or eliminate problems associated with sub-state conditions stationary (eg stick-to-slip vibrations, hole cleaning, side drill bit vibration, side drill column vibration, excessive lateral or axial vibration, etc.). In addition, modalities disclosed here can be employed to proactively introduce or maintain desirable harmonic subsurface conditions (or sets of desirable harmonic subsurface conditions) to mitigate problems such as vibrations due to the stick-slip effect, hole cleaning, lateral vibration of the drill bit, lateral drill column vibration, excessive lateral or axial vibration, etc. By introduction
Petition 870190014537, of 12/02/2019, p. 41/119 / 35 of variations in energy input in the drilling process by selected drilling parameters, selected steady state conditions (leading to drilling process dysfunction) can be avoided. For example, in drilling systems and conventional processes, vibrations due to the adhesion-slip effect can be detected (after the fact) by observing the rotational speed of the constant surface drilling column and varying the rotational speed of the drill bits subsurface drilling rig because of the connection of the drill bit or BHA in the formation. The drill can also observe the increase in torque as the torque accumulates in the drill string because of differences in the rotational speed of the drill string on the surface and the subsurface drill string proximal to the drill bit. In response, the drill typically slows the rotating speed of the drill string on the surface (for example, reducing the RPM of the top row spinning system), to completely rotate the drill string, and slowly releases the tension energy stored in the drill column repeatedly releasing and resetting the actuation brake. Then, the drill typically raises the drill string, resumes rotation of the drill string and drill bit (off the bottom), slowly lowers the drill bit back on the bottom, raises WOB and resumes drilling. However, according to process 200, by oscillating one or more of the drilling parameters above and below their corresponding setpoint between a maximum and minimum value, vibrations due to the sticky-slip effect can preemptively be avoided before it occurs. As another example, dysfunctional vibrations of the drill column exacerbated by resonance can be avoided. Specifically, as the drill bit cuts through the rock, it can initiate the slope. The drill bit does not really come out of the bottom, however, the WOB measured on the surface starts to slide up and
Petition 870190014537, of 12/02/2019, p. 42/119 / 35 low at a relatively high frequency. If the energy imparted to the surface drilling system is in resonance with this reaction, the gap amplitude may increase, which can be translated into radial and torsional vibrations. Although measuring and controlling resonance in real time is challenging, preemptive avoidance of such resonance conditions can be achieved by oscillating the energy input in the drilling process over time according to the modalities described here.
[0052] Although modalities described here concern the oscillation of one or more drilling parameters during drilling operations to create or maintain non-stationary subsurface conditions, it should be realized that the general concept of varying and oscillating operational parameters to create or maintaining non-steady-state subsurface conditions can be applied to other subsurface processes such as cementing operations, descending and rising operations, coating operations, etc. For example, during cementing operations, the flow rate and / or pressure of the cement pumped into the subsurface can be fluctuated over time around corresponding predetermined set points and between corresponding minimum and maximum values. As another example, during coating operations, one or more of the rotational speed, rotational acceleration, axial speed, and axial acceleration of the coating that is descending into the borehole can be oscillated over time around corresponding predetermined set points and between corresponding minimum and maximum values. As yet another example, when descending or ascending a borehole, the rotational speed, rotational acceleration, speed and axial acceleration of the drill string can be oscillated over time around corresponding predetermined set points and between minimum values and corresponding maximums.
Petition 870190014537, of 12/02/2019, p. 43/119 / 35 [0053] Although preferred modalities have been shown and described, modifications of them can be made by those skilled in the art without departing from the revealed scope or precepts. The modalities described here are only exemplary and are not limiting. Many variations and modifications of the systems, apparatus and processes described herein are possible and are within the scope of the invention. For example, the relative dimensions of various parts, the materials from which the various parts are made, and other parameters can be varied. Thus, the scope of protection is not limited to the modalities described here, but is only limited by the following claims, the scope of which must include all equivalents of the subject matter of the claims.

权利要求:
Claims (19)
[1]
1. Method for drilling a borehole (26) in a land formation, characterized by the fact that it comprises:
(a) providing a drilling system (10) including a drilling column (20) with a longitudinal axis, a downhole assembly coupled to a lower end of the drilling column (20), and a drill bit (50 ) coupled to a lower end of the downhole assembly;
(b) rotating the drill bit (50) at rotational speed;
(c) applying weight on the drill bit (50) to the drill bit and advancing the drill bit (50) through the formation to form the borehole (26);
(d) pumping a drilling fluid down the drilling column (20) to the drilling bit (50), where the drilling fluid has a flow rate below the drilling column (20);
(e) oscillate the rotational speed of the drill bit (50) during (c), in which the oscillations of the rotary speed of the drill bit (50) have a period that is less than 10 seconds, and in which the oscillations of the drill bit rotational speed of the drill bit (50) has a random period or random amplitude; and (f) generating non-steady state conditions in the borehole (26) during (e).
[2]
2/6
2. Method according to claim 1, characterized in that the rotational speed of the drill bit (50) is oscillated around a predetermined rotational speed adjustment point.
[3]
3/6 in which (f) comprises oscillating the sum of the first amount of energy, the second amount of energy and the third amount of energy.
Method according to claim 2, characterized in that the rotational speed of the drill bit (50) is maintained between a predetermined maximum rotational speed and a predetermined minimum rotational speed.
Petition 870190014537, of 12/02/2019, p. 11/45
[4]
4/6 (e) controllably oscillate one or more of the following drilling parameters during (c):
the rotational acceleration of the drill bit (50);
the axial speed of the drill bit (50);
the axial acceleration of the drill bit (50);
the flow rate of the drilling fluid below in the drilling column (20); and the pressure of the drilling fluid at the inlet of the drilling column (20).
4. Method according to claim 2, characterized by the fact that the predetermined setpoint for the rotational speed varies with time.
[5]
5/6 (b) monitor the rotational speed of the drill string (20);
(c) controlling the rotational speed of the drill string (20); and (d) oscillate the rotational speed of the drilling column (20) around the predetermined setpoint for the rotational speed and between the predetermined maximum rotational speed and the predetermined minimum rotational speed, where the oscillations of the rotational speed of the drill bit drilling (50) has a period that is less than 10 seconds, and the oscillations in the rotational speed of the drill bit (50) have a random period or random amplitude.
5. Method according to claim 1, characterized by the fact that it additionally comprises:
(g) oscillate the axial speed or axial acceleration of the drill bit (50) during (c).
[6]
6/6 drilling, and a predetermined set point for the flow rate of the drilling fluid;
(f) monitor the flow rate of the drilling fluid;
(g) control the flow rate of the drilling fluid; and (h) oscillate the flow rate of the drilling fluid between the predetermined maximum flow rate and the minimum predetermined flow rate in general around the predetermined setpoint for the flow rate.
6. Method according to claim 1, characterized in that the axial speed of the drill bit (50) is oscillated around a set point of the predetermined axial speed, and in which the axial speed of the drill bit ( 50) is maintained between a predetermined maximum axial speed and a predetermined minimum axial speed.
[7]
7. Method according to claim 6, characterized by the fact that it additionally comprises:
(h) oscillate the flow rate of the drilling fluid below in the drilling column (20) during (c).
[8]
Method according to claim 7, characterized in that the oscillations in the axial speed of the drill bit (50) and the flow rate of the drilling fluid each have a period that is less than 10 seconds.
[9]
Method according to claim 8, characterized in that the oscillations of the axial speed of the drill bit (50) and the flow rate of the drilling fluid each have a random period or a random amplitude.
[10]
10. Method according to claim 2, characterized in that the rotation of the drill string (20) generates a first amount of energy, the axial movement of the drill string (20) generates a second amount of energy, and the drilling fluid flow generates a third amount of energy; and
Petition 870190014537, of 12/02/2019, p. 46/119
[11]
11. Method for maintaining non-steady state conditions in a borehole (26) that is being drilled in a land formation, characterized by the fact that it comprises:
(a) torque a drill bit (50) to rotate the drill bit (50), where the drill bit (50) has a rotational speed and rotational acceleration, and the drill bit (50 ) is coupled to a lower end of the drill string (20);
(b) applying weight on the drill bit to the drill bit (50) to advance the drill bit (50) through the formation to form the borehole (26), where the drill bit (50) has a axial speed and axial acceleration;
(c) pumping a drilling fluid down the drilling column (20) to the drilling bit (50), where the drilling fluid has a flow rate below the drilling column (20) and a pressure at an inlet the drilling column (20);
wherein the rotational speed of the drill bit (50), the rotational acceleration of the drill bit (50), the axial speed of the drill bit (50), the axial acceleration of the drill bit (50), the flow rate the drilling fluid below in the drilling column (20) and the pressure of the drilling fluid at the inlet of the drilling column (20) are each a drilling parameter;
(d) oscillate the rotational speed of the drill bit (50) during (b), in which the oscillations of the rotary speed of the drill bit (50) have a period that is less than 10 seconds, and in which the oscillations of the drill bit rotational speed of the drill bit (50) has a random period or random amplitude;
Petition 870190014537, of 12/02/2019, p. 47/119
[12]
12. Method according to claim 11, characterized in that each controllably oscillated drilling parameter is oscillated around a predetermined set point.
[13]
13. Method according to claim 12, characterized in that each controllable oscillation drilling parameter is oscillated between a maximum predetermined value and a minimum predetermined value.
[14]
14. Method according to claim 12, characterized in that the oscillations of each controllably oscillated drilling parameter have a period of less than 10 seconds.
[15]
15. Method according to claim 14, characterized in that the oscillations of each controllably oscillated drilling parameter have a period of less than 5 seconds.
[16]
16. Computer-readable storage media, characterized by the fact that it has instructions stored in it that, when executed by a processor, make the processor:
(a) receiving a predetermined maximum rotational speed for a drill string (20), a predetermined minimum rotational speed for the drill string (20), and a predetermined set point for the rotational speed of the drill bit (50);
Petition 870190014537, of 12/02/2019, p. 11/48
[17]
17. Computer-readable storage media according to claim 16, characterized by the fact that the instructions additionally make the processor:
(e) receiving a predetermined maximum axial speed for the drill string (20), a predetermined minimum axial speed for the drill string (20), and a predetermined setpoint for the axial speed of the drill string (20);
(f) monitor the axial speed of the drill string (20);
(g) controlling the axial speed of the drill string (20); and (h) oscillate the axial speed of the drill string (20) between the predetermined maximum axial speed and the minimum predetermined axial speed in general around the predetermined setpoint for axial speed.
[18]
18. Computer-readable storage media according to claim 17, characterized in that the instructions additionally cause the processor to:
(e) receive a predetermined maximum flow rate for a drilling fluid, a predetermined minimum flow rate for a drilling fluid
Petition 870190014537, of 12/02/2019, p. 11/49
[19]
19. Computer-readable storage media according to claim 18, characterized in that the instructions additionally cause the processor to:
monitor a plurality of subsurface conditions in a borehole (26) during a drilling process;
oscillate the rotational speed of the drilling column (20), the axial speed of the drilling column (20) and the flow rate of the drilling fluid in response to the subsurface conditions in the borehole (26).

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法律状态:
2018-12-18| B06T| Formal requirements before examination|

2019-01-08| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|

2019-04-02| B09A| Decision: intention to grant|

2019-05-28| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 21/09/2010, OBSERVADAS AS CONDICOES LEGAIS. (CO) 20 (VINTE) ANOS CONTADOS A PARTIR DE 21/09/2010, OBSERVADAS AS CONDICOES LEGAIS |

优先权:

申请号 | 申请日 | 专利标题

US24433509P| true| 2009-09-21|2009-09-21|

US61/244335|2009-09-21|

PCT/US2010/049575|WO2011035280A2|2009-09-21|2010-09-21|Systems and methods for improving drilling efficiency|

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