Vibrating screen condition monitoring

Abstract

A mud vibrating screen system includes a vibrating screen and a fluid sampling circuit connected to a collection device or storage tank of the vibrating screen system. The fluid sampling circuit may include one or more of a pump, pressure sensor, vent valve, flow meter, or coarse filter. The fluid sampling circuit is used to monitor the condition or health of the vibrating screen. The mud vibrating screen system may include a flushing circuit for cleaning the coarse filter. Related methods include using differential pressure, flow rate, or other metrics in the fluid sampling circuit to monitor the condition or health of the vibrating screen. The method may include flushing the fluid sampling circuit to clean it.

Description

[0001] Cross-references to related applications

[0002] This application claims the benefit of U.S. Provisional Patent Application No. 63 / 602,254, filed November 22, 2023, entitled "Systems and Methods for Shaker Screen Condition Monitoring," the entire contents of which are incorporated herein by reference for all purposes.

[0003] Statement regarding federally funded research or development

[0004] not applicable. Background Technology

[0005] Vibrating screening equipment (“mud screens”) is integrated into process flows as a device to separate unwanted materials from desired materials. While vibrating screening equipment is widely used in oil and gas exploration and production, other industries such as mining also rely on screening equipment with the linear vibration and fine screening capabilities of mud screens. As seen in chemical plants, paper mills, sand plants, powder plants, plastics plants, and other separation plants, the process industry also utilizes screening and vibrating equipment in various separation applications.

[0006] In the oil and gas industry, drilling fluid (also known as “mud”) is a critical component during well construction. For example, to extract hydrocarbons from underground formations, a drilling system comprising a drill string configured to deliver drilling fluid into the borehole is used to form a wellbore. The drill string may include a drill bit located at its end and configured to cut into the formation. In some applications, the drilling fluid is configured to provide hydrostatic well control and lubricate the drill bit. The drilling fluid can simultaneously cool the drill bit and carry solid material (called drill cuttings) produced by the drill bit to the surface through the annulus formed between the drill string and the borehole. The cuttings and debris carried to the surface by the drilling fluid provide particularly useful information about the wellbore being formed and the drilling process. Drilling fluid is a mixture of various chemicals in a water-based or oil-based solution and is very expensive to manufacture. For environmental reasons and to reduce the cost of drilling operations, drilling fluid is often recycled and reused, but this requires removing solids from the drilling fluid to avoid operational problems and equipment damage. Therefore, to allow for the reuse of the drilling fluid, a series of screening devices called mud vibrating screens are used at the surface to separate drill cuttings and other solids from the drilling fluid. The drilling fluid is then recirculated through the drilling assembly, while the drill cuttings are sent to separate tanks for analysis or disposal. Attached Figure Description

[0007] A detailed description of the disclosed exemplary embodiments will now be given with reference to the accompanying drawings, in which: Figure 1 This is a schematic diagram of an embodiment of an exemplary drilling system based on the principles disclosed herein; Figure 2 This is a schematic diagram of an embodiment of an exemplary well circulation system based on the principles disclosed herein; Figure 3 This is a top view of an exemplary embodiment of a vibrating screen based on the principles disclosed herein; Figure 4 This is a top view of an exemplary damaged vibrating screen according to the principles disclosed herein, including enlarged portions A, B, and C of the vibrating screen; Figure 5 This is a schematic diagram of an embodiment of an exemplary vibrating screen condition monitoring system based on the principles disclosed herein; Figure 6 yes Figure 5 A perspective view of the pump and fluid path section of the vibrating screen condition monitoring system; Figure 7 This is a schematic diagram of another embodiment of an exemplary vibrating screen condition monitoring system based on the principles disclosed herein; Figure 8 yes Figure 7 A perspective view of the pump and fluid path section of the vibrating screen condition monitoring system; Figure 9 This is a perspective view of yet another embodiment of an exemplary vibrating screen condition monitoring system based on the principles disclosed herein; Figure 10 This is a perspective view of yet another embodiment of an exemplary vibrating screen condition monitoring system based on the principles disclosed herein; Figure 11 It is based on the principles disclosed in this article. Figure 10 Various views of embodiments of exemplary motor mounts; and Figure 12 This is a schematic diagram of an embodiment of an exemplary computing system for monitoring the condition of a vibrating screen, based on the principles disclosed herein. Detailed Implementation

[0008] The following discussion pertains to various embodiments. However, those skilled in the art will understand that the examples disclosed herein have broad applications, and the discussion of any embodiment is merely illustrative of that embodiment and is not intended to imply that the scope of this disclosure, including the claims, is limited to that embodiment. The drawings are not necessarily drawn to scale. Certain features and components in this document may be enlarged or shown in some schematic form, and for clarity and brevity, some details of conventional elements may not be shown.

[0009] In the following discussion and claims, the terms “comprising” and “including” are used in an open-ended manner and should therefore be interpreted as meaning “including, but not limited to…”. Furthermore, the term “couple” is intended to indicate an indirect or direct connection. Thus, if a first device is coupled to a second device, the connection can be a direct connection or an indirect connection achieved via other devices, components, and connections. Additionally, as used herein, the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., the central axis of a body or port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For example, axial distance refers to a distance measured along or parallel to the central axis, and radial distance refers to a distance measured perpendicular to the central axis. Any references to “up” or “down” in the specification and claims are for clarity, wherein “up,” “superior,” “upward,” “upper,” or “upstream” means a surface toward the borehole, and wherein “down,” “lower,” “downward,” “downstream,” or “downstream” means toward the end of the borehole, regardless of borehole orientation.

[0010] As mentioned above, vibratory screening equipment is used to separate unwanted materials from desired materials. Vibratory screening equipment is often referred to as a "mud vibrator" because it uses vibratory motion or "vibration" during the filtration process. In the oil and gas industry, whether onshore or offshore, drilling is considered one of the first steps in the process of extracting hydrocarbon-based resources, and mud vibrators are crucial during drilling because they are the first line of defense against solids contamination, as solids bypassing the mud vibrator can lead to significant operating costs. In addition to the cost of having to filter the same solids more than once, increased chemical consumption, fluid dilution, reduced drilling speed, and equipment damage are additional effects of solids contamination in drilling fluids.

[0011] A mud vibrating screen typically consists of a vibrating screen platform and multiple filter screen components aligned adjacent to each other within the vibrating screen platform to filter drill cuttings from drilling mud. The filter screen components are primarily a frame and wire mesh, the size of which is determined by the target particle size to be removed, thus employing one or more layers of mesh to prevent solids larger than a certain diameter from passing through. The maximum particle size that a given vibrating screen will allow to pass through is called the filtration “separation point.” The screen layers act as a screening mechanism, while the frame provides structural integrity to the screen as it operates under severe vibration, temperature, and load. Due to the intense vibrations applied to these screens during the filtration process, the fine stainless steel wire mesh of the vibrating screen eventually fails due to friction between the screen and the drill cuttings. These screens eventually wear down, and abrasion, tearing, and perforation in these screens begin to deliver larger, more damaging particles into the working drilling fluid system. Screen failure or damage can occur when the wire mesh panels deteriorate or break to the point that particles outside the desired range pass through these screens, which can lead to changes in fluid properties, damage to upstream equipment, and problems in the drilling process. Therefore, the goal is to identify when damage to the screen panel occurs, causing particles above the target range to pass through, and to notify the operator that preventative or corrective actions can be taken.

[0012] Traditionally, drilling rig operators periodically perform visual inspections to identify screen damage and then decide whether to repair the damaged screen unit, replace the screen, or continue operation with the screen in its current condition. However, drilling rig operators often find it difficult to visually identify damaged screens because they are frequently covered with mud and chips while vibrating screen equipment is operating. Typically, operators may have to wait for the mud to clear from the vibrating screen before inspecting it. Furthermore, monitoring vibrating screens is not the only task of the operator, so often, screen damage is not identified until many hours or even days have passed without being filtered, after defects have occurred and large amounts of solids larger than the separation point have already passed through without being filtered. Therefore, the embodiments described herein relate to systems and methods for monitoring the condition of vibrating screens that do not require visual inspection of the vibrating screen by drilling rig operators and do not require waiting for the mud to clear from the vibrating screen or stopping the operation of the mud vibrating screen. Although used for monitoring the condition of vibrating screens, the systems and methods disclosed herein can also be used to monitor the condition of vibrating screens and defects in the seals associated with the vibrating screen.

[0013] Embodiments of the systems and methods for monitoring the condition of vibrating screens described herein include sampling a portion of used drilling fluid that has passed through a vibrating screen and pumping the drilling fluid sample through a loop comprising one or more coarse filters and one or more sensors to monitor the condition or health of the vibrating screen. As used herein, a coarse filter refers to any device capable of separating suspended particles from a fluid (e.g., drilling fluid). In some embodiments, the vibrating screen condition monitoring system includes one or more vibrating screens comprising multiple screen units having multiple layers arranged in a sandwich configuration, one or more fluid inlet or port, one or more fluid outlet ports, one or more fluid pumps, one or more coarse filters having one or more inlet and outlet ports and replaceable filter elements, one or more sensors, and one or more vent valves for cleaning the coarse filter. In some embodiments, the vibrating screen condition monitoring system may include one or more pressure sensors for measuring fluid pressure or differential pressure across one or more coarse filters and / or observing the fluid flow rate through one or more coarse filters. In some embodiments, the vibrating screen condition monitoring system may also include a multi-port valve for changing the direction of fluid flow to flush any build-up or debris in the fluid sampling loop. In some embodiments, the vibrating screen condition monitoring system may include one or more flow meters for measuring the flow rate through one or more coarse filters. In some embodiments, the vibrating screen condition monitoring system may include one or more flow meters and one or more pressure sensors placed upstream of the coarse filter to detect fluid flow through the slurry vibrating screen, thereby preventing misreading of the flow meters.

[0014] In some embodiments, the vibrating screen condition monitoring system may also include a vibrating motor for moving viscous fluid through the system to prevent buildup or clogging. For example, if the fluid sample contains chips or solid material, the filter elements in the coarse filter may become clogged, creating flow restriction and resulting in an increase in fluid pressure or differential pressure between the inlet and outlet of the coarse filter, which can be measured by one or more pressure sensors. Clogging in the coarse filter can also reduce or completely block fluid flowing through one or more coarse filters, which can be visually observed or measured by one or more flow meters. In particular, the operator can identify the condition or health of the vibrating screen by monitoring pressure sensor readings and observing the flow rate through the coarse filter, monitoring flow meter readings, or by monitoring both pressure sensor and flow meter readings. Additionally, the timing or frequency of clogging in the coarse filter can indicate the severity of damage to the vibrating screen. In some embodiments, the pressure sensor and flow meter may be coupled to a computing system on the rig or at a remote location, which can notify rig personnel when the measured pressure and / or flow rate exceeds a predetermined threshold. In some embodiments, information obtained from the vibrating screen condition monitoring system can be used to train machine learning algorithms to detect the condition of the vibrating screen and the severity of damage to the vibrating screen.

[0015] refer to Figure 1 This document illustrates an embodiment of an exemplary well or drilling system 10 for drilling or producing hydrocarbons from a well or wellbore, based on the principles disclosed herein. In this exemplary embodiment, the drilling system 10 typically includes a vertical support structure or derrick 12 supported by a drilling platform 14. The platform 14 includes a drilling deck or rig 16 supporting a rotary table 18 selectively rotated by a prime mover (not shown), such as an electric motor controlled by a motor controller. The derrick 12 includes a traveling block 20 controlled by a winch 22 for raising and lowering a drill string 24 suspended from the traveling block 20. The drill string 24 of the drilling system 10 extends downward through the rotary table 18, a blowout preventer (BOP) assembly 26, and into a wellbore 3 that extends along a central or longitudinal axis 15 from the surface 7 into the subsurface formation 5. The drill string 24 is formed by a plurality of end-to-end drill pipe joints 28. In this exemplary embodiment, the bottom hole assembly (BHA) 30 is attached to the lowest rod connector 28, and the drill bit 32 is attached to the downhole end of the BHA 30. In other embodiments, the drilling system 10 may include an offshore drilling system comprising a drill string extending through a marine riser and into a subsea wellbore.

[0016] In this embodiment, the drill bit 32 rotates together with the rotary table 18 via the drill string 24 and BHA 30. By rotating the drill bit 32, to which pressure on drill (WOB) is applied, the drill bit 32 breaks down the subsurface formation to drill the wellbore 3. In some embodiments, a top drive may be used to rotate the drill string 24 instead of via the rotary table 18. In some applications, instead of or in addition to rotating the drill string 24 from the surface 7, a downhole motor (mud motor) 35 is disposed in the drill string 24 to rotate the drill bit 32. Specifically, the mud motor 35 can rotate the drill bit 32 as drilling fluid passes under pressure through it. In this exemplary embodiment, the casing string 34 is installed and extends generally downwards from the surface 7 into at least a portion of the wellbore 3. In some embodiments, the casing string 34 is cemented within the wellbore 3 to isolate the respective vertically separated formation regions and prevent fluid transfer between regions. The BOP assembly 26 is secured to the upper end of the casing string 34. The casing string 34 may include multiple tubular components, such as threaded pipes that are joined end-to-end to form a liquid-tight or gas-tight connection to prevent fluid and pressure exchange between the wellbore 3 and the surrounding formation area.

[0017] An annular space or annulus 36 is formed between the sidewall 9 of the wellbore 3 and the drill string 24, and between the inner surface of the casing string 34 and the drill string 24. In other words, the annulus 36 extends through the wellbore 3 and the casing string 34. The BOP assembly 26 includes an annular space or flow path in fluid communication with the annulus 36. The operator or drilling control system of the drilling system 10 can selectively and controllably open and close one or more BOPs of the BOP assembly 26 to allow, restrict, or inhibit the flow of drilling fluid or another fluid through the annulus 36. In this exemplary embodiment, the drilling system 10 includes a drilling fluid circulation system 50 to circulate drilling fluid or mud 40 down the drill string 24 and back into the annulus 36.

[0018] refer to Figure 1 and Figure 2This document illustrates an embodiment of an exemplary drilling fluid circulation system 50 based on the principles disclosed herein. The drilling fluid circulation system 50 includes a drilling fluid reservoir or mud tank 42, a supply pump 44, a supply line 46 connected to the outlet of the supply pump 44, a screed 48 for supplying drilling fluid 40 to the drill string 24, and a mud vibrating screen 52 for separating used drilling fluid 40 from drill cuttings. The drilling fluid 40 is typically used to cool the drill bit 32, remove drill cuttings from the bottom of the wellbore 3, and maintain a desired pressure or pressure distribution within the wellbore 3 during drilling operations. In this exemplary embodiment, the drilling fluid 40 is mixed in the mud tank 42 and pumped by the mud pump 44 through the supply line 46 and the screed 48, descending along the drill string 24 via the BOP 26 to the drill bit 32. The drilling fluid 40 then exits the nozzle of the drill bit 32 and flows upward along the annulus 36 between the drill string 24 and the wellbore 3, thereby lifting drill cuttings to the surface 7. Drilling fluid 40 carrying drill cuttings flows through mud vibrating screen 52, where it is separated from drill cuttings and other solid particles by vibrating screen mesh 60. The screened drilling fluid 40 can then be directed back to mud tank 42 for reuse. While the drilling system 10 and drilling fluid circulation system 50 have been generally described, it will be understood that in other embodiments, the configuration of the drilling system 10 and drilling fluid circulation system 50 may differ. Figure 1 and Figure 2 The configuration shown.

[0019] Now for reference Figure 3 This illustration shows an embodiment of an exemplary vibrating screen assembly 60 based on the principles disclosed herein. The vibrating screen assembly 60 may include a perforated plate 62 on which a plurality of screen units 70 are mounted. These screen units 70 comprise one, two, three, or more layers of screening material arranged in a sandwich configuration, i.e., screens, meshes, and / or cloths made, for example, of stainless steel wire, plastic filament, or molded fabric. The screening material layers (e.g., screen unit layers 72, 74, and 76) may be bonded together, for example, by gluing, welding, and / or sintering in any manner, and attached to the plate 62 in any suitable manner. The plate 62 includes a plurality of side holes 64 on each of two opposite sides for receiving releasable fasteners for mounting the screen assembly 60 in a suitable slurry vibrating screen, such as… Figure 2 52. Mud vibrating screen.

[0020] Now for reference Figure 4 This illustrates an exemplary embodiment of a damaged vibrating screen according to the principles disclosed herein. As described above, each of the plurality of screen units 70 of the vibrating screen 60 may include one, two, three or more unit layers arranged in a sandwich configuration (e.g., Figure 3(Unit layers 72, 74, and 76). For example, depending on which one or more screen unit layers are damaged, the screen unit condition can be classified as undamaged A, missing or torn top layer B, or unit blowout C. In one embodiment, a unit blowout may occur when all unit layers (e.g., Figure 3 The unit layers 72, 74 and 76) were damaged to the point that drilling fluid (e.g., Figure 2 Large particles in the drilling fluid (40) do not obstruct the path of the screen unit. When there is a missing or torn top layer, only the coarser middle and bottom layers are retained to limit the size of the particles that can pass through. Therefore, the operator can decide that only the missing or torn top layer of the vibrating screen needs to be repaired, rather than completely removing or replacing the entire vibrating screen.

[0021] As previously mentioned, mud vibrating screens form the first stage of solids control in many industries, including oil and gas drilling. To identify defects in the vibrating screen and prevent damage to drilling equipment, drilling operators can periodically inspect the screen for defects. However, periodic inspections by drilling personnel can be ineffective and can lead to costly delays and downtime due to the presence of drilling fluid on the screen during operation. Therefore, the embodiments described herein relate to a system, which may be referred to as a vibrating screen condition monitoring system, for monitoring the condition of the vibrating screen and associated seals without requiring visual inspection by drilling personnel and without waiting for mud to be removed from the screen or stopping the operation of the mud vibrating screen.

[0022] Now for reference Figures 5 to 6 This document illustrates an embodiment of an exemplary vibrating screen condition monitoring system 100 based on the principles disclosed herein. In some embodiments, the vibrating screen condition monitoring system 100 includes a fluid sampling loop comprising at least one fluid sampling loop inlet or port 103 fluidly connected to a mud tank, at least one fluid sampling loop outlet or port 104 fluidly connected to the mud tank, and one or more vibrating screens 120 mounted within the mud tank, each vibrating screen 120 comprising a plurality of screen units (e.g., Figure 3 The sieve unit 70), each sieve unit has multiple unit layers (e.g., Figure 3 (Unit layers 72, 74, and 76). The fluid sampling loop also includes at least one coarse filter 110, each coarse filter including a filter element (not shown) with a mesh size equal to or larger than the mesh on the vibrating screen 120, one or more fluid pumps 130, a vent valve 140 coupled to the coarse filter 110 to release blockages and remove solid material from the coarse filter, and pressure sensors 150 located on either side, upstream, or downstream of the coarse filter 110 and in fluid communication with the coarse filter 110. The coarse filter 110 may be located upstream or downstream of the pump 130. Although in Figures 5 to 6 Two pressure sensors 150 are shown, but other numbers of pressure sensors can be used.

[0023] As described above and in Figure 5 As best illustrated, used drilling fluid 40 can flow from the drilling fluid inlet 101 in the mud tank through a vibrating screen 120, where drill cuttings and other solid materials separate from the drilling fluid and are discarded through the outlet 102 in the mud tank. After flowing through and then through the vibrating screen 120, the drilling fluid 40 flows into a vibrating screen equipment reservoir 105 downstream of the vibrating screen 120, where a portion or sample of the drilling fluid 40 that has passed through the vibrating screen 120 can be drawn into a fluid sampling loop inlet 103 and pumped by a fluid pump 130 through a sampling loop containing a coarse filter 110. The pump 130 can be of any type suitable for fluid movement, and the fluid sample can be drawn from any portion downstream of the vibrating screen. For example, the fluid sample can be drawn from a manifold or inlet port located in the reservoir 105. The manifold can be designed with adjustable orientation to draw fluid from a preferred location in the reservoir 105. Additionally, fluid samples can be drawn from a tray in storage tank 105 with a discharge port for collecting fluid samples. This tray can be part of the mud vibrating screen design. When a fluid sample flows through coarse filter 110, if solid material or debris is present in the fluid sample, the screen in the filter element of coarse filter 110 may become clogged, creating fluid flow restriction in coarse filter 110, resulting in an increase in pressure that can be measured by pressure sensor 150.

[0024] In some embodiments, two pressure sensors 150 are present, and they may be located on opposite sides of the coarse filter 110, such as... Figure 5 As shown, the pressure difference between the two sensors can indicate flow restriction within the coarse filter 110. In other embodiments, a pressure sensor 150 is used, and the pressure sensor 150 can be located upstream of the coarse filter 110, and the pressure reading in the pressure sensor 150 can indicate flow restriction within the coarse filter 110. Additionally, flow restriction in the coarse filter 110 can also lead to a reduction or complete interception of fluid flowing through the coarse filter 110, which can be visually observed by the operator. In other embodiments, no pressure sensor is present, and the discharge flow rate in the sampling loop can be used to assess flow restriction in the coarse filter 110. For example, the discharge flow rate in this sampling loop can decrease as the accumulation of solid material in the coarse filter 110 increases. In particular, by monitoring the pressure sensor 150 and / or by observing the flow rate through the coarse filter 110, the operator can identify the condition of the vibrating screen 120.

[0025] In some embodiments, after a defect in the vibrating screen 120 is detected and the vibrating screen 120 is repaired or replaced, the vent valve 140 can be used to clean the coarse filter 110 and remove any solid material that may be clogging the filter of the coarse filter 110 before resuming operation of the vibrating screen condition monitoring system 100. Cleaning the coarse filter 110 can be achieved by opening the attached vent valve 140, thereby forcing the material accumulated in the coarse filter 110 through a separate outlet (not shown) and discarding it.

[0026] Additionally, in some embodiments, the vibrating screen condition monitoring system 100 can be configured to alarm the operator when the sensor pressure or differential pressure across the coarse filter 110 exceeds a predetermined threshold. For example, the pressure sensor 150 can be connected to a computing system located on the drilling rig or at a remote center for managing drilling rig operations, so that the operator can be notified when the sensor pressure or differential pressure across the coarse filter 110 is greater than or equal to the threshold. For example, if the sensor pressure or differential pressure across the coarse filter 110 is less than or equal to 10 psi, the operator can be notified, and the operator can decide to continue operating the mud vibrating screen; however, if the sensor pressure or differential pressure across the coarse filter 110 is greater than 10 psi, the operator can decide to stop operating the mud vibrating screen to inspect, repair, or replace the vibrating screen.

[0027] Now for reference Figures 7 to 8 This illustrates another embodiment of an exemplary vibrating screen condition monitoring system 200 based on the principles disclosed herein. The vibrating screen condition monitoring system 200 includes... Figures 5 to 6 The vibrating screen condition monitoring system 200 shown shares common features, and shared components are similarly labeled. Specifically, in this exemplary embodiment, the vibrating screen condition monitoring system 200 typically includes one or more flushing inlets 203 fluidly connected to a mud tank, a flushing outlet 204 fluidly connected to a mud tank, a coarse filter 210 for filtration and flushing, and one or more multi-port valves 240 fluidly connected to the coarse filter 210 and used to change the direction of fluid flow to flush any accumulated fluid (e.g., high-viscosity fluid), solid material, or debris in the sampling loop. Figure 8 In some embodiments, fluid flows into the flushing circuit from the flushing inlet 203 and passes through the coarse filter 210, and is pumped through the coarse filter 210 to loosen and / or remove any blockages in the coarse filter 210. The fluid used for flushing may be drilling fluid that has already passed through the vibrating screen 120, or it may be fluid drawn from a separate source. After flushing, the fluid flows out through the flushing outlet 204 to the vibrating screen equipment reservoir (e.g., Figure 5The fluid can be transferred to a storage tank 105 or via a separate return line, and the fluid sampling loop can be restored to operation as described in the vibrating screen condition monitoring system 100. The multi-port valve 240 and one or more relief valves 140 can be manual or have different levels of automation.

[0028] Now for reference Figure 9 This illustrates another embodiment of an exemplary vibrating screen condition monitoring system 300 based on the principles disclosed herein. The vibrating screen condition monitoring system 300 includes a fluid collection tray (not shown) having a shape equivalent to that of a mud vibrating screen (e.g., Figure 2 The length of the outlet of the mud vibrating screen 52 and the height of approximately 4 inches for capturing the fluid leaving the mud vibrating screen, the fluid sampling inlet 303, and one or more vibrating screens (e.g., Figure 5 The system includes a vibrating screen 120, at least one coarse filter 310 (each coarse filter having a mesh size matching the mesh size on the vibrating screen), one or more flow meters 360 connected to the coarse filter 310, and one or more pressure sensors 350 connected to the slurry vibrating screen. In some embodiments, the one or more flow meters 360 may be located upstream and downstream of the coarse filter 310. Each coarse filter 310 includes a filter element. When the fluid that has passed through the vibrating screen (e.g., Figure 1 As drilling fluid 40 flows from the fluid collection tray into the fluid sampling inlet 303, the fluid is directed to the coarse filter 310 under the fluid momentum from the mud vibrating screen reservoir. This allows the coarse filter 310 to become clogged if any debris or solid material is present, resulting in flow restriction that can be detected by one or more flow meters 360 downstream of the coarse filter 310. In particular, if the coarse filter element of the coarse filter 310 is clogged with debris or solid material, fluid may not pass through, resulting in reduced or no fluid flow. In some embodiments, the vibrating screen condition monitoring system 300 may include one or more pressure sensors 350 located upstream of the coarse filter 310 to detect fluid flow through the mud vibrating screen, thereby preventing misreading by the flow meters 360.

[0029] In some embodiments, one or more flow meters 360 may be coupled to a computing system on the drilling rig or at a remote location, which may activate an alarm system to notify the operator when the flow rate through the coarse filter 310 drops below a predetermined threshold. For example, if the flow meter 360 reads a non-zero value above a predefined threshold, the computing system may not indicate a screen malfunction and may not send an alarm. However, if the flow meter 360 reads zero and the pressure sensor 350 records an increase, the computing system may indicate a screen malfunction and notify the operator. Additionally, if the flow meter 360 reads zero and the pressure sensor 350 does not record a pressure increase, the computing system may indicate that the mud vibrating screen is currently not in operation (i.e., the mud pump is off, drilling has stopped, etc.). Although Figure 9 A vibrating screen condition monitoring system 300 with a pressure sensor 350 and a flow meter 360 is shown, but it will be understood that the vibrating screen condition monitoring system 300 may include one or more flow meters and one or more pressure sensors as described.

[0030] Now for reference Figure 10 This illustrates another embodiment of a vibrating screen condition monitoring system 400 based on the principles disclosed herein. The vibrating screen condition monitoring system 400 includes... Figure 9 The vibrating screen condition monitoring system 300 shown shares common features. Specifically, the vibrating screen condition monitoring system 400 includes a vibrating motor 480 coupled to a coarse filter 410 having filter elements, and one or more flow meters 460 located upstream and downstream of the coarse filter 410 and fluidly coupled to the coarse filter 410. The vibrating motor 480 can be mounted to the coarse filter 410 to activate the system and allow more viscous drilling fluid to pass through the coarse filter 410, thereby preventing clogging. The vibrating motor 480 can be mounted using a motor mounting bracket 490. Figure 11 The design of motor mount 490 is shown in the figure.

[0031] A computer system 500 suitable for implementing one or more embodiments disclosed herein is illustrated. For example, notifications or operator alarms from the described vibrating screen condition monitoring system may include the computing system 500 (such as a desktop computer, laptop computer, tablet computer, smartphone, web server, or other suitable device known in the art) or at least some of the features of the computing system 500. In some embodiments, the computing system implementing the notifications or operator alarms from the vibrating screen condition monitoring system may include multiple separate computer systems located on and / or remotely from the drilling platform 14. The computing system 500 includes a processor 502 (which may be referred to as a central processing unit or CPU) that communicates with memory devices including auxiliary memory 504, read-only memory (ROM) 506, random access memory (RAM) 508, input / output (I / O) devices 510, and network connectivity devices 512. The processor 502 may be implemented as one or more CPU chips. It should be understood that by programming executable instructions and / or loading executable instructions onto the computing system 500, at least one of the CPU 502, RAM 508, and ROM 506 is modified, thereby partially transforming the computing system 500 into a particular machine or apparatus having novel functions taught by this disclosure.

[0032] Additionally, after system 500 is powered on or started, CPU 502 can execute computer programs or applications. For example, CPU 502 can execute software or firmware stored in ROM 506 or RAM 508. In some cases, at startup and / or when an application is launched, CPU 502 can copy the application or portions of the application from secondary memory 504 to RAM 508 or the memory space within CPU 502 itself, and then CPU 502 can execute instructions included in the application. During execution, the application can load instructions into CPU 502, for example, loading some of the application's instructions into the CPU 502's cache. In some contexts, it can be said that the executed application configures CPU 502 to do certain things, for example, configuring CPU 502 to perform one or more functions initiated by the subject application. When CPU 502 is configured by the application in this way, CPU 502 becomes a dedicated computer or dedicated machine.

[0033] Secondary memory 504 can be used to store programs, which are loaded into RAM 508 when selected for execution. For example, processor 502 can be configured to execute instructions retrieved from memory 504 to analyze sensor data received from one or more pressure sensors and / or one or more flow meters. To perform this operation, computing system 500 may include machine learning algorithms configured to train processor 502 to analyze the condition of the vibrating screen and determine the severity of damage. Processor 502 can also compare sensor readings to predefined thresholds and alert the operator.

[0034] ROM 506 is used to store instructions and, possibly, data read during program execution. ROM 506 is a non-volatile memory device, typically having a smaller memory capacity relative to the larger memory capacity of secondary memory 504. Secondary memory 504, RAM 508, and / or ROM 506 may be referred to as computer-readable storage media and / or non-transitory computer-readable media in some contexts. I / O device 510 may include a printer, video monitor, liquid crystal display (LCD), touch screen display, keyboard, keypad, switch, dial pad, mouse, trackball, voice recognizer, card reader, paper tape reader, or other known input devices.

[0035] Network connectivity device 512 may take the form of a modem, modem group, Ethernet card, Universal Serial Bus (USB) interface card, Wireless Local Area Network (WLAN) card, radio transceiver card, and / or other known network devices. Network connectivity device 512 can provide wired and / or wireless communication links. These network connectivity devices 512 enable processor 502 to communicate with the Internet or one or more intranets. Using such a network connection, it is conceivable that processor 202 can receive information from the network or output information to the network.

[0036] Processor 502 executes its instructions, code, computer programs, and scripts accessed from hard disk, optical disk, flash drive, ROM 506, RAM 508, or network-connected device 512. Although only one processor 502 is shown, multiple processors may be present. Therefore, while instructions may be discussed as being executed by a processor, those instructions may be executed simultaneously, serially, or otherwise by one or more processors. Instructions, code, computer programs, scripts, and / or data accessible from secondary memory 504 (e.g., hard disk, optical disk, and / or other devices), ROM 506, and / or RAM 508 may, in some contexts, be referred to as non-transitory instructions and / or non-transitory information.

[0037] In an embodiment, computing system 500 may include two or more computers communicating with each other and collaborating to perform tasks. For example, but not limited to, an application may be partitioned to allow concurrent and / or parallel processing of the application's instructions. Alternatively, the data processed by the application may be partitioned to allow different portions of the dataset to be processed concurrently and / or in parallel by the two or more computers. In an embodiment, the functionality disclosed above may be provided by executing one or more applications in a cloud computing environment. Cloud computing may include providing computing services via network connections using dynamically scalable computing resources.

[0038] While the disclosed embodiments have been shown and described, modifications can be made to them by those skilled in the art without departing from the scope or teachings herein. The embodiments described herein are exemplary and not restrictive. Many variations and modifications of the systems, apparatuses, and processes described herein are possible and are within the scope of this disclosure. Therefore, the scope of protection is not limited to the embodiments described herein, but is limited only by the appended claims, the scope of which should include all equivalents of the subject matter of the claims. Unless expressly stated otherwise, the steps in the method claims may be performed in any order. The recitation of identifiers such as (a), (b), (c) or (1), (2), (3) before the steps in the method claims is not intended to, and does not specify, a particular order of steps, but is used to simplify subsequent references to these steps.

Claims

1. A system comprising: A mud vibrating screen, the mud vibrating screen comprising one or more vibrating screens, each vibrating screen having multiple screen units; as well as A fluid sampling circuit, comprising: One or more fluid sampling inlet ports, the one or more fluid sampling inlet ports being configured to receive samples of drilling fluid that have passed through the vibrating screen; One or more fluid sampling outlet ports, the one or more fluid sampling outlet ports being configured to discharge sampled drilling fluid from the fluid sampling loop into a vibrating screen equipment storage tank; One or more fluid pumps configured to pump the sampled drilling fluid through the fluid sampling loop; One or more pressure sensors; One or more relief valves; and One or more coarse filters, each coarse filter including a filter element, one or more inlet ports, and one or more outlet ports, wherein the mesh size of the filter element is greater than or equal to the mesh size of the vibrating screen, and wherein the coarse filter is fluidly connected to the vent valve and the sensor.

2. The system according to claim 1, wherein, The vent valve is configured to loosen solid material or debris that is clogging the coarse filter.

3. A system comprising: A mud vibrating screen, the mud vibrating screen comprising one or more vibrating screens, each vibrating screen having multiple screen units; A fluid sampling circuit includes: one or more fluid sampling inlet ports configured to receive samples of drilling fluid that have passed through the vibrating screen; one or more fluid sampling outlet ports configured to discharge fluid from the fluid sampling circuit into a storage tank of the vibrating screen; one or more fluid pumps configured to pump fluid through the sampling circuit; one or more vent valves; and one or more coarse filters, wherein the coarse filters include filter elements, one or more inlet ports, and one or more outlet ports, the mesh size of the filter elements being greater than or equal to the mesh size on the vibrating screen, and wherein the vent valves are connected to the coarse filters; and A fluid flushing circuit includes flushing fluid, one or more multi-port valves configured to change the direction of fluid flow in the fluid sampling circuit, one or more flushing inlets, one or more flushing outlets, and one or more coarse filters, wherein the coarse filters are coupled to the multi-port valves.

4. The system according to claim 3, wherein, The flushing fluid may be the same as or different from the sampled fluid.

5. The system according to claim 3, wherein, The rinsing circuit and the sampling circuit may be the same or different.

6. The system according to claim 3, wherein, The fluid flow direction in the flushing circuit is opposite to the fluid flow direction in the sampling circuit.

7. A system comprising: A mud vibrating screen, the mud vibrating screen comprising one or more vibrating screens, each vibrating screen having multiple screen units; Fluid collection equipment; One or more fluid inlet ports configured to receive a portion or sample of drilling fluid that has passed from the fluid collection device through the vibrating screen; One or more fluid outlet ports, the one or more fluid outlet ports being configured to discharge fluid into the storage tank of the vibrating screen equipment; One or more flow meters; as well as One or more coarse filters, each with a mesh size equal to that of the vibrating screen, each coarse filter having one or more inlet ports and one or more outlet ports, wherein the coarse filters are connected to the flow meter.

8. The system of claim 7 further includes one or more pressure sensors placed upstream of the coarse filter and coupled to the slurry vibrating screen, wherein the pressure sensors are configured to detect fluid flowing in the vibrating screen device.

9. The system according to claim 7, wherein, One flow meter is placed upstream of the coarse filter, and another flow meter is placed downstream of the coarse filter.

10. The system of claim 7, wherein the collecting device comprises a length equal to the outlet of the mud vibrating screen.

11. The system according to claim 7 further includes a vibration motor.

12. The system of claim 11, wherein the vibration motor includes a motor mounting member for mounting the vibration motor on the system.

13. A method comprising: The sample of drilling fluid that has passed through the vibrating screen is received through the inlet port of the fluid sampling loop; The drilling fluid sample is pumped through a fluid sampling circuit, which includes one or more coarse filters having one or more inlet ports, one or more outlet ports, and filter elements. The mesh size of the filter elements is greater than or equal to the mesh size of the vibrating screen. The coarse filters are connected to one or more sensors and one or more relief valves. as well as The sampled fluid is discharged into the storage tank of the vibrating screen equipment through the outlet of the fluid sampling loop.

14. The method of claim 13 further includes observing the flow rate through the coarse filter.

15. A method comprising: Receive flushing fluid through the inlet port of the fluid flushing circuit; The flushing fluid is pumped through a fluid flushing circuit, the fluid flushing circuit comprising: one or more coarse filters having one or more inlet ports, one or more outlet ports, and filter elements having a mesh size greater than or equal to the mesh size of a vibrating screen connected to the fluid flushing circuit; and one or more multi-port valves, wherein the coarse filters are connected to the multi-port valves; The flushing fluid is discharged into the storage tank of the vibrating screen equipment through the outlet of the fluid flushing circuit; The sample of drilling fluid that has passed through the vibrating screen is received through the inlet port of the fluid sampling loop; The sampled fluid is pumped through a fluid sampling circuit, which includes one or more vent valves, one or more coarse filters, each coarse filter having one or more inlet ports, one or more outlet ports, and a filter element, wherein the mesh size of the filter element is greater than or equal to the mesh size of the vibrating screen; wherein the coarse filter is connected to one or more sensors and one or more vent valves. as well as The sampled fluid is discharged into the storage tank of the vibrating screen equipment through the outlet of the fluid sampling loop.

16. The method according to claim 15, wherein, The flushing fluid may be the same as or different from the sampled fluid.

17. The method of claim 15 further includes observing the flow rate through the coarse filter.

18. A method comprising: Receive samples of drilling fluid that have passed through a vibrating screen from the fluid collection equipment; The sampled fluid is passed through one or more coarse filters, the one or more coarse filters having one or more inlet ports, one or more outlet ports and filter elements, the filter elements having a mesh size greater than or equal to the mesh size of the vibrating screen, wherein the coarse filters are connected to one or more flow meters; Observe the flow rate flowing through the flow meter; and The sampled fluid is discharged into the storage tank of the vibrating screen equipment through the fluid outlet.

19. The method of claim 18, further comprising one or more pressure sensors, wherein the pressure sensors are located upstream of the coarse filter and are coupled to the mud vibrating screen.

20. The method of claim 19, comprising observing readings from the pressure sensor.

Images