BR122024000315A2 - DEVICE - Google Patents

Abstract

An apparatus includes a shaker screen into which downhole materials and fluid from a well are to be placed, the downhole materials are a product of a downhole operation, and a shaker for vibrating the shaker screen. to separate downhole materials from the fluid. The apparatus includes a radar for emitting an electromagnetic wave onto the downhole materials in at least one of the shaker screen and a transit and detecting a reflection of the reflected electromagnetic wave from at least a portion of the downhole materials and a device for determining a velocity of downhole materials advancing along at least one of the agitator screen toward a discharge end of the agitator screen and transit.

Description

Technical field

[001] The disclosure generally refers to the field of downhole hydrocarbon recovery and, more particularly, to measuring the velocity of drilled cuttings and cuttings in an agitator.

Fundamentals

[002] Increase the effectiveness of pumping, sweeping, drilling, fracturing operations, etc. can reduce the cost of hydrocarbon recovery operations. One approach to increasing the effectiveness of such operations is to observe the characteristics of various particles that return to the Earth's surface from the bottom of the well during different hydrocarbon recovery operations.

Brief description of the drawings

[003] The modalities of the disclosure can be better understood with reference to the attached drawings.

[004] FIG. 1 is a block diagram of an example system for measuring volume based on the velocity of downhole cuttings and cuttings, in accordance with some embodiments.

[005] FIG. 2 is a side view of a discharge end of an agitator screen free of debris and cuttings, in accordance with some embodiments.

[006] FIG. 3 is a side view of a discharge end of an agitator screen with fragments and cuttings, in accordance with some embodiments.

[007] FIGS. 4-5 are flowcharts of operations for measuring volume based on the velocity of downhole cuttings and cuttings, in accordance with some embodiments.

[008] FIG. 6 is a schematic diagram of a drilling rig system, in accordance with some embodiments.

[009] FIG. 7 is an example computer, in accordance with some embodiments.

Description of modalities

[0010] The following description includes examples of systems, methods, techniques and program flows that incorporate aspects of disclosure. However, it is understood that this disclosure may be made without these specific details. For example, this disclosure refers to drilling as a downhole operation in illustrative examples. Aspects of this disclosure may also be applied to any other type of downhole operation that results in cuttings and cuttings or any other downhole particles reaching the well surface (e.g., fracturing). In other cases, well-known instruction instances, protocols, structures, and techniques were not shown in detail so as not to overshadow the description.

[0011] Various embodiments relate to measuring or determining a velocity of cuttings and cuttings reaching the Earth's surface during a downhole operation (e.g., drilling) as the cuttings advance through an agitator. However, various modalities should not be limited to measuring the velocity of drilled cuttings and cuttings. Some embodiments can also be used to monitor the tilt angle of the agitator, thereby monitoring the health of the agitator, as well as monitoring changes in mud density or rheological parameters of the return mud that affect transport speed. Both cuttings and cuttings and fluids can come to the surface during downhole operation. Consequently, the fragments and cuttings and fluids are transferred to an upper surface of the agitator. The top surface of the shaker can be a screen, so that fluids fall off, leaving fragments and grit. During operation, the agitator vibrates and the screen can be configured as a conveyor to move the cuttings and cuttings from a first end to a second end (or a "discharge end"), resulting in the cuttings and cuttings falling from the cutting end. discharge.

[0012] An approximate area of the cuttings and cuttings in the agitator (known as the “area under the curve”) can also be measured or determined in addition to the speed of the cuttings and cuttings. Measuring the speed and approximate area of the cuttings in the shaker can be used to determine the volume of cuttings and cuttings at or during a given period of time. The total volume of cuttings and cuttings received from the bottom of the hole and processed by the shaker for a particular zone or location in the formation being drilled can then be determined by adding measurements of the volume of cuttings and cuttings for the time periods that were associated with the fragments and gravel from that certain area or location. The total volume of cuttings can also be determined for a particular downhole operation, a particular time of a particular downhole operation, etc.

[0013] Without measuring the speed of fragments and cuttings, errors may occur in determining the volume of fragments and cuttings. Conventional approaches to measuring speed include approximations and inferences made by dropping a known particle into the stirrer and measuring the time for the distance traveled. However, these conventional approaches tend to induce errors in calculations. For example, these conventional approaches do not provide a continuous reading of speed and do not take changes in speed into account. Furthermore, such approaches can increase the system cost substantially if this process of falling a known particle at certain time intervals is automated.

[0014] Various embodiments use radar (RAdio Detection And Ranging) to track the movement of particles moving on a shaker screen. The selected radar may be a radar that transmits a narrow band of electromagnetic waves and may be of high resolution. In some embodiments, the radar is positioned to emit electromagnetic waves at a discharge end of the stirrer screen. This position of the radar ensures that cuttings and cuttings velocities are being captured at the discharge end of the shaker screen rather than the middle of the shaker screen, where cuttings and cuttings speeds may be greater.

[0015] The velocity obtained from the radar can be integrated into a cuttings and cuttings volume platform that includes measuring an area of the moving cuttings on the shaker screen, or the area under the curve. A volume measurement of a cuttings and cuttings can be calculated by multiplying the velocity of a cuttings and cuttings by the area of the cuttings and cuttings. Therefore, a total volume measurement of the cuttings and cuttings can be made by adding a volume measurement of each cuttings and cuttings moving through the shaker screen. Using radar to measure the speed of cuttings and gravel moving along the shaker screen overcomes the challenges of vibration, variable ambient lighting, fog, mechanical variation, mud splash, high cost, etc. which introduce error into speed determination with conventional approaches.

[0016] In some embodiments, an optical device can make optical measurements of the area of fragments and cuttings. For example, optical devices can be positioned above a shaker screen to make optical measurements. Alternatively or in addition, optical devices can be positioned at the discharge end of the shaker screen to make optical measurements. Radar can also be used to determine the tilt of the shaker. The speed of particles leaving the stirrer can be correlated to the tilt angle of the stirrer. Due to continuous high-frequency vibration, changes in shaker inclination during operation are likely to go undetected. However, knowing whether the shaker tilt angle has changed makes it easier to maintain the integrity of the shaker. Excessive downward tilt can cause increased particle velocity, as well as loss of drilling mud and cuttings, thus increasing the cost of operations. On the other hand, excessive upward tilting of the agitator can cause particles to remain on the agitator screen longer, slowing down the particles and eventually causing the particles to settle on the agitator screen (or “ blinding” the shaker screen). Increases in return mud density or other rheological parameters can also cause particle velocity to decrease. Using the correlation between particle velocity and shaker tilt, the integrity of the shaker and shaker screen can be monitored as changes occur. Any substantial change in speed can be incorporated as an alarm, thus providing more opportunities for agitator health monitoring or monitoring changes in mud density or return mud rheological parameters that affect conveying speed.

Example System

[0017] FIG. 1 is a block diagram of an example system for measuring volume based on the velocity of downhole cuttings and cuttings, in accordance with some embodiments. A system 100 comprises a combination of an imaging device 124, a radar 190 and one or more processors 130. The imaging device 124, the radar 190 and/or the processors 130 may be located above the surface 166 of a geological formation, perhaps forming part of a data acquisition system 152. In some embodiments, the imaging device 124 may comprise one or more CCD (charge coupled device) or CMOS (complementary metal oxide semiconductor) cameras, including low light cameras or infrared.

[0018] System 100 may also include logic 140, perhaps comprising a programmable data acquisition subsystem. Logic 140 may be used to acquire live video stream information 128 and other data such as downhole information, including the depth of a drill bit during a drilling operation.

[0019] A memory 150, located above or below surface 166, may be used to store acquired image data captured by imaging device 124 and reflection data detected by radar 190, as well as other data (e.g., perhaps in a database 134). Memory 150 is communicatively coupled to processor(s) 130. Imaging device 124 and radar 190 are communicatively coupled to processors 130. Processors 130 can control imaging device 124 and radar 190. Although it represents only a radar, the system 100 may include multiple radars that are positioned to emit an electromagnetic wave to a discharge end 198 of a shaker screen 108. Although Figure 1 depicts the radar 190 as positioned toward a shaker screen, the System 100 may include any other transit placed downstream of agitator 104 that is used to transport material, such as by means of vibration, plunger action, conveyor, or other means. Radar 190 can thus be positioned towards this traffic.

[0020] During operation, downhole cuttings and cuttings 112 together with fluids are routed from the well and deposited on the shaker screen 108 at its front end 199. The cuttings and cuttings 112 and fluids move towards the discharge end 198 of the agitator screen, while an agitator 104 causes the agitator screen 108 to vibrate to more easily separate fragments and cuttings 112 from the fluids. During this operation, the radar 190 emits an electromagnetic wave 192 toward the fragments and cuttings 112 at or near the discharge end 198. A reflection 194 of the electromagnetic wave is reflected from the fragments and cuttings and detected by the radar 190. As further described below , the reflections detected by the radar 190 are used to determine a speed of the fragments and cuttings 112 as they move through the shaker screen 108. The tilt angle of the shaker screen 108 can also be monitored during operation.

[0021] The imaging device 124 can capture images of the fragments and cuttings 112 on the shaker screen 108. As further described below, the images of the fragments and cuttings 112 can be used to determine an area of the fragments and cuttings 112. In turn , a volume of the cuttings and cuttings 112 may be derived from the velocity and area of the cuttings and cuttings 112. Processors 130 may also be configured to publish the volume of cuttings and cuttings 112 in conjunction with the likely conditions associated with a well operation. (e.g. drilling, fracturing, etc.). Alternatively or in addition, processors 130 may modify well operation based on the volume of cuttings and cuttings 112.

[0022] Radar 190 may include the following: 1) a transmitter that creates the energy pulse; 2) a transmit/receive switch for controlling when a radar antenna 190 should transmit pulses and when it should receive pulses; 3) an antenna to transmit the pulses into the atmosphere and receive the reflected pulses; and 4) a receiver that detects, amplifies and transforms received signals into video format. In some embodiments, radar 190 operates in the microwave region of the electromagnetic spectrum at frequencies extending from approximately 400 MegaHertz (MHz) to 40 GigaHertz (GHz). The radar 190 can extract the frequency change of the reflected signal produced by a moving target based on the difference between the frequency of the received signal and the frequency of the signal that was transmitted.

[0023] To capture speed, a 4-20 milliampere (mA) signal, RS-232/485 or any other communication protocol can be used. The radar 190 may be connected to the data acquisition system 152 via shielded or unshielded intrinsically safe cables. The data acquisition system 152 may use intrinsically safe barriers or may be a remote input/output (I/O) system. The data acquisition system 152 may be certified for areas classified as Zone 1. To minimize multiple cable runs, the fiber/copper cable may run from a local Zone 1 certified data acquisition system 152 to a secure area ( e.g. a mud profiling device). The data acquisition system 152 may be connected to a network computer 156 and database, such as the database 134 in memory 150. Graphical user interfaces (GUIs) may be created to plot speed and/or speed readings. or trends on a 196 display.

[0024] The speed of cuttings and cuttings 112 can also be used to monitor its correlation with the shaker tilt angle, monitor the health of the shaker 104, and/or account for accidental and/or unwanted changes in the shaker 104. The speed can be monitored throughout the duration of the operation to track sudden changes in return mud density or other rheological properties that affect transport speed.

[0025] FIG. 2 is a side view of a discharge end of an agitator screen free of debris and cuttings, in accordance with some embodiments. In particular, FIG. 2 represents a side view of a discharge end 202 of an agitator screen 200 which may be an example of the discharge end 198 of the agitator screen 108 depicted in FIG. 1. Fragments and cuttings (e.g., cuttings and cuttings 112) from the bottom of the well that are deposited on the shaker screen 200 move through the shaker screen 200 toward the discharge end 202.

[0026] FIG. 3 is a side view of a discharge end of an agitator screen with fragments and cuttings, in accordance with some embodiments. In particular, FIG. 3 is a side view of the discharge end 202 of the agitator screen 200 of FIG. 2 which includes fragments and cuttings 302. An area 304 of the fragments and cuttings 302 can be determined by processing the images captured by the imaging device 124 (as described below). Although FIGS. 2-3 describe the shaker screen as a flat screen, the shaker screen can be any other type of screen (such as corrugated, etc.) A radar, such as radar 190 of FIG. 1, captures the velocity of the cuttings and cuttings 302 as the cuttings and cuttings 302 reach the discharge end 202 of the agitator screen 200. The radar 190 transmits an electromagnetic wave to capture the speed of the cuttings and cuttings 302 as close to the end as possible. discharge tip 202 to avoid contact with portions of the cuttings and cuttings 302 that are closest to the center of the agitator screen 200. Volume measurements may be inaccurate if the speed of the cuttings and cuttings 302 is measured too far from the discharge end 202 , since the speed may be greater in this region of the stirrer screen 200.

Example operations

[0027] Example operations for determining volume fragments and cuttings based on speed and area measurements of the fragments and cuttings are now described. FIGS. 4-5 are flowcharts of operations for measuring volume based on the velocity of downhole cuttings and cuttings, in accordance with some embodiments. Operations of flowcharts 400-500 of FIGS. 4-5 continue with each other through transition points A-B. The operations of flowcharts 400-500 may be performed by software, firmware, hardware, or a combination thereof. Flowchart operations 400 begin at block 402.

[0028] In block 402, a downhole operation is carried out which results in cuttings and cuttings and fluid reaching the surface of the Earth. For example, the downhole operation could be drilling, fracturing, etc. An example of a drilling operation is shown in FIG. 5, which is described in more detail below.

[0029] In block 404, the fragments and cuttings and the fluid are deposited on a shaker screen to separate the fragments and cuttings from the fluid. For example, with reference to FIG. 1, the fluid and fragments and cuttings 112 are deposited on the agitator screen 108.

[0030] In block 406, an electromagnetic wave is emitted, using a radar, toward the fragments and cuttings at a discharge end of the agitator screen. For example, in FIG. 1, the radar 190 emits the electromagnetic wave 192 toward the fragments and cuttings 112 at the discharge end 198 of the shaker screen 108. As another example, the radar 190 emits the electromagnetic wave toward the fragments and cuttings 302 at the discharge end 202 of the shaker screen 200 shown in FIG. 3.

[0031] In block 408, a reflection of the electromagnetic wave reflected from at least one fragment and gravel on the shaker screen is detected using radar. As an example, in FIG. 1, the radar 190 detects the reflection 194 of the electromagnetic wave 192 that reflected from at least one of the fragments and gravel 112.

[0032] In block 410, a speed of the fragments and cuttings on the agitator screen is determined based on the reflection of the electromagnetic pulse. For example, with reference to FIG. 1, the radar 190 processes the reflection 194 and determines a Doppler frequency based on the difference between the frequency of the electromagnetic wave 192 and the frequency of the reflection 194. The speed can then be determined based on the Doppler frequency and the observed frequencies of the electromagnetic pulses . In some embodiments, radar 190 may transmit the speed of fragments and cuttings 112 to data acquisition system 152 for storage in memory 150. Operations continue at transition point A, which continues at transition point A of flowchart 500.

[0033] In block 512, a determination is made whether a sudden change in the velocity of the fragments and cuttings has occurred. Changes in observed velocity may be indicative of the following changes: changes in drilling parameters, changes in downhole formation, or intentional or accidental changes in the up or down tilt of the shaker. A threshold change in speed can be established, which indicates a magnitude that is considered a change. The threshold value may indicate a maximum magnitude of change in speed that is permitted. For example, at least an X% increase or decrease in speed over N measurements can be defined as a sudden change in speed, where of the well, etc. Examples of the value of X could be 5, 10, 50, etc. Examples of N values could be 1, 2, 3, 10, etc. An increase in speed may be indicative of potential excessive downward tilt of the agitator, while a decrease may be indicative of potential excessive upward tilt of the agitator. Changes in velocity can also be attributed to changes in the density of the drilling mud or other rheological properties of the drilling mud returning to the surface. Additionally, changes in drilling parameters and/or changes in downhole formation can cause an increase in cuttings and cuttings returning from the bottom of the hole. A change in velocity can be a consequence of this increase in downhole returns. To facilitate monitoring of the shaker or shaker screen integrity, if a sudden change in speed is observed, a notification indicating the sudden change can be issued. For example, with reference to FIG. 1, one or more speed calculations stored in memory 150 may be analyzed by processor(s) 130 to determine whether a sudden change in speed has occurred. If the change in speed exceeds a threshold, operations continue at block 514. If the change in speed does not exceed a threshold, operations continue at transition point B, which continues at transition point B of flowchart 400.

[0034] In block 514, a determination is made whether the drilling parameters have changed. Changes in drilling parameters can be checked in a drilling profile. For example, with reference to FIG. 1, drilling parameters and profiled changes to drilling parameters may be stored in a drilling profile in memory 150. Processor(s) 130 may retrieve profiled drilling parameters from memory 150 to determine whether a change has been made. done. If drilling parameters have not changed, operations continue in block 516. If drilling parameters have changed, operations continue in block 522.

[0035] In block 516, a determination is made whether a change in formation has occurred. Changes in downhole formation can be verified by monitoring the depth of drilling operations and comparing the depth with geological formation graphs. For example, a drill bit depth can be compared to an expected formation condition represented on a geological formation chart. If the geological formation condition corresponding to the depth of the drill bit has changed since a previous observation, it can be determined that the formation has changed. Comparison of drilling mud volumes in the drilling well and drilling mud pit can be used alternatively or additionally to verify downhole formation changes. For example, with reference to FIG. 1, the processor(s) 130 may leverage drill bit depth data, drilling mud volumes in the drilling well and drilling mud pit, and geological formation graphs stored in memory 150 for analysis. If a formation change has not occurred, operations continue in block 518. If a formation change has occurred, operations continue in block 522.

[0036] In block 518, a determination is made whether the tilt angle of the shaker screen has changed. For example, with reference to FIG. 1, a sensor may be mounted on the shaker screen 108 that captures the tilt angle of the shaker screen 108. A threshold tilt angle may be established, which indicates a threshold measurement that constitutes a change. For example, the error threshold may be a maximum allowable magnitude of change in the tilt angle of the shaker screen 108. As another example, the error threshold may establish a threshold increase or decrease in the tilt angle of X degrees over N measurements captured by the shaker screen sensor 108 (e.g., a 5 degree threshold increase or decrease captured in 3 measurements, etc.). The tilt angle may have changed intentionally or accidentally (e.g., due to mechanical failures of the stirrer 104). Detected changes in the tilt angle of the shaker screen 108 may be profiled in memory 150 for analysis (e.g., by the processor(s) 130) and/or indicated with a notification output to the screen 196. If the angle If the shaker screen tilt angle has changed, operations continue at block 520. If the shaker screen tilt angle has not changed, operations continue at transition point B, which continues at transition point B of flowchart 400.

[0037] In block 520, a determination is made as to whether the change in the tilt angle of the shaker screen was intentional. Intentional changes in the tilt angle of the shaker screen captured by the sensor can be profiled. For example, with reference to FIG. 1, the tilt angle may be stored in memory 150 following an increase or decrease in the tilt angle of the shaker screen 108. The processor(s) 130 may check whether the detected tilt angle of the shaker screen 108 was profiled to determine that the change was intentional. If the change in the shaker screen tilt angle was intentional, operations continue to block 522. If the change in the shaker screen tilt angle was unintentional (i.e., it was accidental), operations continue to block 524 .

[0038] In block 522, a determination is made that the change in speed is caused by a change in drilling parameters, a change in formation, and/or an intentional change in the tilt angle of the stirrer screen. A notification and/or alarm is generated, which indicates that a change in speed has been detected. The notification and/or alarm may indicate the underlying cause of the change in speed. Alternatively or in addition, the speed change event can be profiled in an event profile. For example, with reference to FIG. 1, a notification and/or alarm may be generated and sent to display 196. The event may also be profiled in memory 150. Operations continue at transition point B, which continues at transition point B of flowchart 400.

[0039] In block 524, a determination is made that the change in speed is caused by an accidental change in the tilt angle of the stirrer screen. Accidental changes in the tilt angle of the shaker screen may arise due to mechanical wear, loosening of screws on the shaker, etc., which may contribute to the loss of drilling mud or may cause damage to the shaker screen. A notification or alarm may be issued that indicates that the change in speed of the cuttings is due to an accidental change in the tilt angle of the shaker screen. Alternatively or in addition, the change in speed and change in bank angle due to unintentional causes can be recorded (e.g. in an event profile). For example, with reference to FIG. 1, the measured bank angle and the detected change in speed may be recorded in an event profile in memory 150. A notification or alarm may also be generated and sent to the display 196. Operations continue at transition point B, which continues at transition point B of flowchart 400.

[0040] In block 412, a size or area of the fragments and cuttings on the shaker screen is determined. In some embodiments, a size or area of the cuttings may be defined as an area of the cuttings ("area under the curve"). For example, with reference to FIGS. 1 and 3, the imaging device 124 can capture an image of the fragments and cuttings 112 at the discharge end 198 of the shaker screen 108. The acquired image data is communicated to the data acquisition system 152. The area 304 of the fragments and gravel 302 as captured in the image data can be determined based on analysis of the image data (e.g., by processor(s) 130). For example, the area 304 under the curve can be determined by identifying the "curve" formed by the upper limit of cuttings 302 at the discharge end 202 above the agitator screen structure 200. The area 304 that is then calculated is the area between the shaker screen 200 and the upper limit, or curve, of the fragments and cuttings 302 in the shaker screen 200. The area 304 of the fragments and cuttings 302 can be stored in memory 150.

[0041] In block 414, a volume of the fragments and cuttings on the agitator screen is determined based on the speed of the fragments and cuttings and the area of the fragments and cuttings on the agitator screen. For example, in FIG. 1, the processor(s) 130 can calculate the volume of the fragments and cuttings 112 by retrieving from memory 150 the speed and area of the fragments and cuttings 112. The processor(s) 130 calculate the volume of the fragments and gravels 112 as the product of velocity and area. In some embodiments, the velocity may be determined less frequently than the approximate area of the cuttings and cuttings because the speed of the cuttings and cuttings tends to change less frequently. For example, the speed may be determined once every minute, every five minutes, every 10 minutes, etc., while an image of the fragments and cuttings is captured and processed every second, every five seconds, every 10 seconds, etc. Therefore, the volume of fragments and cuttings can be calculated after each velocity determination and/or each area determination.

[0042] In block 416, a determination is made whether fragments and cuttings and fluid continue to be deposited on the agitator screen. If so, flowchart operations 400 return to block 408. Otherwise, flowchart operations 400-500 will be completed.

Example drilling application

[0043] FIG. 6 is a schematic diagram of a drilling rig system, in accordance with some embodiments. For example, in FIG. 6, it can be seen how a system 664 can also form a portion of a drilling rig 602 located on the surface 604 of a well 606. Drilling of oil and gas wells is commonly performed using a string of drill pipes connected together. to form a drill string 608 which is lowered via a rotary table 610 into a wellbore or shaft 612. Here, the drilling rig 686 is equipped with a derrick 688 which supports a winch.

[0044] The drilling rig 602 can thus provide support for the drill string 608. The drill string 608 can operate to penetrate the rotary table 610 to drill the well 612 through the subsurface formations 614. The drill string 608 may include a kelly 616, drill pipe 618, and a bottom composition 620, perhaps located in the lower portion of the drill pipe 618.

[0045] The downhole composition 620 may include controls 622, a downhole tool 624, and a drill bit 626. The drill bit 626 may operate to create a well 612 by penetrating the surface 604 and subsurface formations 614. Downhole tool 624 may comprise any of a number of different types of tools including MWD tools, LWD tools and others.

[0046] During drilling operations, the drill string 608 (perhaps including the Kelly 616, the drill pipe 618 and the bottom composition 620) may be rotated by the rotary table 610. In addition to, or alternatively, the Bottom composition 620 may also be rotated by a motor (e.g., a mud motor) that is located at the bottom of the well. The controls 622 may be used to add weight to the drill bit 626. The controls 622 may also operate to stiffen the bottom composition 620, allowing the bottom composition 620 to transfer the added weight to the drill bit 626 and in turn time, assist the drill bit 626 to penetrate the surface 604 and subsurface formations 614.

[0047] During drilling operations, a mud pump 632 may pump drilling fluid (sometimes known to those skilled in the art as "drilling mud") from a mud tank 634 through a hose 636 to the drill pipe 618 and downward to the drill bit 626. The drilling fluid may flow out of the drill bit 626 and return to the surface 604 through an annular area 640 between the drill pipe 618 and the sides of the well 612. The fluid drilling may then return to mud tank 634 where such fluid is filtered. In some embodiments, the drilling fluid may be used to cool the drill bit 626 as well as to provide lubrication for the drill bit 626 during drilling operations. Additionally, the drilling fluid can be used to remove fragments of the subsurface formation 614 created by the operation of the drill bit 626. It is the images of these fragments and cuttings that many embodiments operate to acquire and process.

[0048] Thus, referring now to FIG. 1, it can be seen that in some embodiments, the system 664 may comprise an agitator screen 108 for receiving drilling mud or fluid and cuttings and the system 100 as previously described.

[0049] It should also be understood that the apparatus and systems of various embodiments can be used in applications other than pumping and drilling operations and, thus, various embodiments will not be thus limited. The illustrations of system 100 and system 664 are intended to provide a general understanding of the structure of various embodiments and are not intended to serve as a complete description of all elements and features of apparatus and systems that may make use of the structures described herein.

[0050] Applications that may include the new apparatus and systems of various embodiments include electronic circuits used in high-speed computers, communication and signal processing circuits, modems, processor modules, embedded processors, data switches and specific modules. application. Such devices and systems may further be included as subcomponents within a variety of electronic systems, such as televisions, cell phones, personal computers, workstations, radios, video players, vehicles, signal processing for geothermal tools, and telemetry systems. smart transducer interface node, among others. Some embodiments include a series of methods.

Example computer

[0051] FIG. 7 represents an example computer, according to some embodiments. The computer includes a processor 701 (possibly including multiple processors, multiple cores, multiple nodes and/or multi-threading implementation, etc.). The computer includes memory 707. Memory 707 may be system memory (e.g., one or more of cache, SRAM, DRAM, zero-capacitor RAM, dual-transistor RAM, eDRAM, EDO RAM, DDR RAM, EEPROM, NRAM , RRAM, SONOS, PRAM, etc.) or any one or more of the possible embodiments already described above of machine-readable medium. The computer system also includes a bus 703 (e.g., PCI, ISA, PCI-Express, HyperTransport® bus, InfiniBand® bus, NuBus, etc.) and a network interface 705 (e.g., a Fiber Channel interface, a Ethernet interface, an Internet small computer system interface, SONET interface, wireless interface, etc.).

[0052] The computer also includes an analyzer 711 and a controller 715. The analyzer 711 can perform processing and analysis of downhole cuttings and cuttings based on electromagnetic wave reflections and captured images (as described above). The controller 715 can control the radar and imaging device, as well as the different operations that may occur in response to the analysis results. For example, controller 715 may communicate instructions to equipment, devices, etc. suitable for changing drilling operations. Any of the previously described functionality may be partially (or fully) implemented in hardware and/or in processor 701. For example, the functionality may be implemented with an application-specific integrated circuit, in logic implemented in processor 701, in a coprocessor in a peripheral device or card, etc. Furthermore, embodiments may include fewer components or additional components not illustrated in Figure 7 (e.g., video cards, audio cards, additional network interfaces, peripheral devices, etc.). Processor 701 and network interface 705 are coupled to bus 703. Although illustrated as being coupled to bus 703, memory 707 may be coupled to processor 701. Although depicted as a computer, some embodiments may be any type of device or apparatus to perform the operations described here.

[0053] It will be understood that each block of the flowchart illustrations and/or block diagrams, and combinations of blocks in the flowchart illustrations and/or block diagrams, can be implemented by program code. The program code may be supplied to a processor of a general purpose computer, special purpose computer, or other programmable machine or apparatus.

[0054] As will be appreciated, aspects of the disclosure may be embodied as a system, method, or program code/instructions stored on one or more machine-readable media. Accordingly, the aspects may take the form of hardware, software (including firmware, resident software, microcode, etc.), or a combination of software and hardware aspects which may be generally referred to herein as a "circuit", "module "or "system". The functionality presented as individual modules/units in the example illustrations may be organized differently according to any platform (operating system and/or hardware), application ecosystem, interfaces, programmer preferences, programming language, administrator preferences, etc.

[0055] Any combination of one or more machine-readable media may be used. The machine-readable medium may be a machine-readable signal medium or a machine-readable storage medium. A machine-readable storage medium may be, for example, but not limited to, a system, apparatus or device, which employs any one or a combination of electronic, magnetic, optical, electromagnetic, infrared or semiconductor technology to store the code of the program. More specific examples (a non-exhaustive list) of machine-readable storage media would include the following: a portable computer floppy disk, a hard drive, a random access memory (RAM), a read-only memory (ROM), a memory only erasable programmable read-only memory (EPROM or Flash memory), a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing. In the context of this document, a machine-readable storage medium may be any tangible medium that can contain or store a program for use by or in connection with an instruction execution system, apparatus, or device. A machine-readable storage medium is not a machine-readable signal medium.

[0056] A machine-readable signal medium may include a propagated data signal with machine-readable program code incorporated therein, for example, in baseband or as part of a carrier wave. Such propagated signal may take any of a variety of forms, including, but not limited to, electromagnetic, optical or any suitable combination thereof. A machine-readable signal medium may be any machine-readable medium that is not a machine-readable storage medium and that can communicate, propagate or transport a program for use by or in connection with an execution system, apparatus or device of instruction.

[0057] Program code embodied in a machine-readable medium may be transmitted using any appropriate means, including, but not limited to, wireless cable, steel cable, fiber optic cable, RF, etc., or any appropriate combination of the above.

[0058] Computer program code for performing operations for aspects of the disclosure may be written in any combination of one or more programming languages, including an object-oriented programming language, such as Java® programming language, C++, or the like. ; a dynamic programming language, such as Python; a scripting language, such as Perl programming language or PowerShell scripting language; and conventional procedural programming languages, such as the "C" programming language or similar programming languages. Program code can run entirely on a standalone machine, can run in a distributed manner across multiple machines, and can run on one machine while providing results and/or accepting input on another machine.

[0059] Program code/instructions may also be stored on a machine-readable medium that can direct a machine to function in a particular manner, such that the instructions stored on the machine-readable medium produce an article of manufacture including instructions that implement the function/act specified in the flowchart and/or block or blocks of the block diagram.

[0060] Use of the apparatus, systems, and methods disclosed herein may provide the ability to monitor changes in downhole particles (e.g., cuttings and cuttings) so that the impact of drilling fluid properties and activities on the field can be evaluated immediately. This capability can be used to increase efficiency by redirecting pumping and drilling operations in real time, perhaps as part of a closed-loop control system.

[0061] Although aspects of the disclosure are described with reference to various implementations and exploitations, it will be understood that these aspects are illustrative and that the scope of the claims is not limited thereto. In general, the techniques for processing and analyzing downhole particles as described herein can be implemented with facilities consistent with any hardware system or hardware systems. Many variations, modifications, additions and improvements are possible.

[0062] Plural instances may be provided for components, operations or structures described herein as a single instance. Finally, the boundaries between various components, operations, and data stores are somewhat arbitrary, and specific operations are illustrated in the context of specific illustrative configurations. Other functionality allocations are anticipated and may fall within the scope of the disclosure. In general, the frameworks and functionality presented as separate components in example configurations can be implemented as a combined framework or component. Likewise, structures and functionality presented as a single component can be implemented as separate components. These and other variations, modifications, additions and improvements may fall within the scope of the disclosure.

[0063] The use of the phrase "at least one of" preceding a list with the conjunction "and" should not be treated as an exclusive list and should not be interpreted as a list of categories with one item from each category, unless specifically stated otherwise. A clause that recites “at least one of A, B and C” may be violated with just one of the items listed, several of the items listed, and one or more of the items in the list and one item not listed.

Example modalities

[0064] Example embodiments include the following:

[0065] Embodiment 1: A method comprising: depositing, on a shaker screen, a plurality of downhole materials and fluids arriving at a surface of a well as a result of a downhole operation in the well, in that downhole materials comprise fragments and cuttings; separate, use the shaker screen, the downhole materials from the fluids; emitting, using a radar, an electromagnetic wave towards at least one of a discharge end of the shaker screen and a transit; detecting a reflection of the electromagnetic wave reflected from at least a portion of the downhole materials; and determining, based on the reflection of the electromagnetic wave, a velocity of the downhole material advancing along at least one of the transit and the shaker screen toward the discharge end of the shaker screen.

[0066] Modality 2: The method of Modality 1, further comprising: determining an area of at least the portion of the downhole materials; and determining a volume of the downhole materials based on the velocity of the downhole materials advancing along at least one of the shaker screen toward the discharge end of the shaker screen and the traffic and area of at least the portion of downhole materials.

[0067] Mode 3: The method of Mode 2, wherein determining the volume of the downhole materials comprises calculating a product of the velocity of the downhole materials and the area of at least a portion of the downhole materials .

[0068] Modality 4: The method of any of Modalities 1-3, in which determining the velocity of downhole materials comprises: determining a difference in frequency between the electromagnetic wave emitted by the radar and the reflection of the electromagnetic wave; and calculate the velocity of downhole materials based on the frequency difference.

[0069] Modality 5: The method of any of Modalities 1-4 further comprising correlating an inclination angle of at least one of the stirrer screen and the transit to the velocity of the downhole materials.

[0070] Embodiment 6: The method of Embodiment 5, further comprising determining that the tilt angle of at least one of the shaker screen and the transit needs to be corrected based on the correlation of the tilt angle of at least one of the shaker screen and from transit to the velocity of downhole materials.

[0071] Embodiment 7: The method of Embodiment 6, wherein determining that the tilt angle of at least one of the shaker screen and the transit needs to be corrected comprises: determining whether a change in the velocity of downhole materials has exceeded a speed threshold; and in response to the change in speed exceeding the speed threshold, determine whether the change in speed is the result of a change in an angle of a slope of at least one of the shaker screen and the traffic exceeding an error threshold or an increase in an amount of downhole material returning from the bottom of the hole; generate an alarm for a change in speed; in response to the change in velocity being the result of the increase in the amount of downhole material returning from the bottomhole, determine whether the increase in the amount of downhole material is the result of a change in drilling parameters or a change in formation being drilled and generating an alarm for increased velocity and determining a cause of increasing returns due to change in drilling parameters or a formation being drilled; and in response to the change in speed exceeding the speed threshold being the result of the change in the tilt angle of at least one of the shaker screen and the traffic exceeding the error threshold and that the change in tilt angle was unintentional, generate an alarm that there is an error in the tilt angle of at least one of the shaker and transit screen.

[0072] Embodiment 8: One or more non-transitory machine-readable media comprising program code executable by a processor for making a device: receive a reflection value from a reflection of an electromagnetic wave that has reflected from at least a portion of materials of downhole deposited in at least one of a shaker screen and a transit, wherein the reflection is based on the emission of the electromagnetic wave from a radar towards at least one of a discharge end of the shaker screen and the transit; determining, based on the reflection value, a velocity of the downhole materials advancing along the shaker screen toward at least one of the discharge ends of the shaker screen and transit; determining an area of downhole materials in at least one of the shaker screen and transit; and determining a volume of the downhole materials based on the velocity of the downhole materials advancing along the shaker screen toward the discharge end of the shaker screen and the area of the downhole materials on the shaker screen .

[0073] Embodiment 9: The one or more non-transitory machine-readable means of Embodiment 8, wherein the program code for determining the volume of the downhole materials comprises program code executable by the processor to cause the device to calculate a product of the velocity of the downhole materials and the area of the downhole materials.

[0074] Embodiment 10: The one or more non-transitory machine-readable means of Embodiment 8 or 9, wherein the program code for determining the velocity of downhole materials comprises program code executable by the processor for making the device: determine a difference in frequency between the electromagnetic wave emitted by the radar and the reflection of the electromagnetic wave; and calculate the velocity of downhole materials based on the frequency difference.

[0075] Embodiment 11: The one or more non-transitory machine-readable media of any of Embodiments 8-10 further comprising program code executable by the processor to cause the device to correlate a tilt angle of at least one of the screen agitator and transit for the velocity of downhole materials.

[0076] Embodiment 12: The one or more non-transitory machine-readable means of Embodiment 11, further comprising program code executable by the processor for causing the device to determine the tilt angle of at least one of the shaker screen and the transit needs to be corrected based on the correlation of the tilt angle of at least one of the shaker screen and the transit to the velocity of the downhole materials.

[0077] Embodiment 13: The one or more non-transitory machine-readable means of Embodiment 12, wherein the program code for determining that the tilt angle of at least one of the shaker screen and the transit needs to be corrected comprises the code of the program executable by the processor to make the device: determine whether a change in the velocity of downhole materials exceeded a velocity threshold; and in response to the change in speed exceeding the speed threshold, determine whether the change in speed is the result of a change in an angle of a slope of at least one of the shaker screen and the traffic exceeding an error threshold or an increase in an amount of downhole material returning from the bottom of the hole; generate an alarm for a change in speed; in response to the change in velocity being the result of the increase in the amount of downhole material returning from the bottomhole, determine whether the increase in the amount of downhole material is the result of a change in drilling parameters or a change in formation being drilled and generating an alarm for increased velocity and determining a cause of increasing returns due to change in drilling parameters or a formation being drilled; and in response to the change in speed exceeding the speed threshold being the result of the change in the tilt angle of at least one of the shaker screen and the traffic exceeding the error threshold and that the change in tilt angle was unintentional, generate an alarm that there is an error in the tilt angle of at least one of the shaker and transit screen.

[0078] Embodiment 14: An apparatus comprising: a shaker screen into which downhole materials and fluid from a well are to be placed, the downhole materials a product of a downhole operation; a shaker to vibrate the shaker screen to separate downhole materials from the fluid; a radar for emitting an electromagnetic wave onto the downhole materials in at least one of the shaker screen and a transit and detecting a reflection of the electromagnetic wave reflected from at least a portion of the downhole materials; and a device for determining a velocity of downhole materials advancing along at least one of the shaker screen toward a discharge end of the shaker screen and transit.

[0079] Embodiment 15: The apparatus of Embodiment 14 further comprising the device for: determining an area of downhole materials in at least one of the agitator screen and the transit; and determining a volume of the downhole materials based on the velocity of the downhole materials advancing along at least one of the shaker screen toward the discharge end of the shaker screen and the transit and area of the shaker screen materials. bottoming out in at least one of the shaker screen and the transit.

[0080] Embodiment 16: The apparatus of Embodiment 15, wherein the device for determining the volume of the downhole materials comprises the device for calculating a product of the velocity of the downhole materials and the area of the downhole materials .

[0081] Embodiment 17: The apparatus of any of Embodiments 14-16, wherein the device for determining the velocity of downhole materials comprises the device for: determining a difference in frequency between the electromagnetic wave emitted by the radar and the electromagnetic wave reflection; and calculate the velocity of downhole materials based on the frequency difference.

[0082] Embodiment 18: The apparatus of any of Embodiments 14-17, further comprising the device for correlating an inclination angle of at least one of the agitator screen and the transit with the velocity of the downhole materials.

[0083] Embodiment 19: The apparatus of Embodiment 18, further comprising the device for determining that the tilt angle of at least one of the agitator screen and the transit needs to be corrected based on correlating the tilt angle of at least one of the shaker screen and transit to speed downhole materials.

[0084] Embodiment 20: The apparatus of Embodiment 19, wherein the device for determining that the angle of inclination of at least one of the agitator screen and the transit needs to be corrected comprises the device for: determining whether a change in the speed of the materials downhole exceeded a velocity threshold; and in response to the change in speed exceeding the speed threshold, determining whether the change in speed is the result of a change in an angle of a slope of at least one of the agitator screen and the traffic or an increase in an amount of material of bottomhole returning from the bottom of the well; generate an alarm for a change in speed; in response to the change in velocity being the result of the increase in the amount of downhole material returning from the bottomhole, determine whether the increase in the amount of downhole material is the result of a change in drilling parameters or a change in formation being drilled and generating an alarm for increased velocity and determining a cause of increasing returns due to change in drilling parameters or a formation being drilled; and in response to the change in speed exceeding the speed threshold being the result of the change in the tilt angle of at least one of the shaker screen and the traffic exceeding the error threshold and that the change in tilt angle was unintentional, generate an alarm that there is an error in the tilt angle of at least one of the shaker and transit screen.

Claims (7)

1. Apparatus, characterized by the fact that it comprises: - a shaker screen into which the downhole materials and fluid from a well are to be placed, the downhole materials are a product of a downhole operation; - a shaker to vibrate the shaker screen to separate downhole materials from the fluid; - a radar for emitting an electromagnetic wave onto the downhole materials in at least one of the shaker screen and a transit and detecting a reflection of the reflected electromagnetic wave from at least a portion of the downhole materials; and - a device for determining a velocity of downhole materials advancing along at least one of the agitator screen toward a discharge end of the agitator screen and transit. 2. Apparatus according to claim 1, characterized by the fact that it further comprises the device for: - determining an area of the downhole materials in at least one of the agitator screen and the transit; and - determine a volume of the downhole materials based on the velocity of the downhole materials advancing along at least one of the shaker screen toward the discharge end of the shaker screen and the transit and area of the materials downhole in at least one of the shaker and transit screen. 3. Apparatus according to claim 2, characterized in that the device for determining the volume of the downhole materials comprises the device for calculating a product of the velocity of the downhole materials and the area of the downhole materials . 4. Apparatus according to claim 1, characterized in that the device for determining the velocity of downhole materials comprises the device for: - determining a difference in frequency between the electromagnetic wave emitted by the radar and the reflection of the electromagnetic wave ; and - calculate the velocity of downhole materials based on the frequency difference. 5. Apparatus according to claim 1, further comprising the device for correlating an inclination angle of at least one of the agitator screen and the transit with the velocity of the downhole materials. 6. Apparatus according to claim 1, further comprising the device for determining that the tilt angle of at least one of the agitator screen and the transit needs to be corrected based on the correlation of the tilt angle of at least one of the agitator screen and the transit. minus one from the shaker screen and transit to speed downhole materials. 7. Apparatus according to claim 6, characterized in that the device for determining that the angle of inclination of at least one of the agitator screen and the traffic needs to be corrected comprises the device for: - determining whether a change in speed of downhole materials exceeded a velocity threshold; and - in response to the change in speed exceeding the speed threshold, - determining whether the change in speed is a result of a change in an angle of a slope of at least one of the shaker screen and the traffic exceeding an error threshold or an increase in the amount of downhole material returning from the bottom of the hole; - generate an alarm for a change in speed; - in response to the change in velocity being the result of the increase in the amount of downhole material returning from the bottomhole, - determining whether the increase in the amount of downhole material is the result of a change in drilling parameters or a change in the formation being drilled and generate an alarm for increased velocity and determine a cause of increasing returns due to change in drilling parameters or a formation being drilled; and - in response to the change in speed being the result of the change in the tilt angle of at least one of the shaker screen and the traffic exceeding the error threshold and the change in tilt angle was unintentional, - generating a traffic alarm that there is an error in the tilt angle of at least one of the shaker screen and the transit.