Patent Publication Number: US-11384611-B2

Title: Enhancing screw geometry

Description:
BACKGROUND 
     Drilling fluids may be circulated through a wellbore during a drilling operation, for example, to remove cuttings (i.e., small pieces of the formation that break away during drilling) and to cool the drill bit. In some instances, drilling fluids are an oil-based fluid that includes a weighting agent. Typically, weighting agents include particles of high-density minerals that increase the density of the drilling fluid. Increasing the density of the drilling fluid may help to stabilize the wellbore and mitigate formation fluid intrusion into the wellbore. 
     As drilling fluids are circulated through the wellbore during the drilling process, the drilling fluids collect drilled solids or “cuttings.” These cuttings affect the properties of the drilling fluid. Accordingly, drilling fluids may be passed through a series of processes or apparatuses to remove the cuttings (e.g., vibrating screens for filtration). However, as the drilling continues, the cuttings are further broken down into smaller and smaller particles that cannot be effectively removed by normal mechanical means. Further, the density of cuttings is often sufficiently low that gravity or centrifugal methods to remove the cuttings is inefficient or ineffective. Once the properties of the drilling fluid are deemed unfit for drilling, the drilling fluid is considered to be a “spent” drilling fluid and/or a drilling waste fluid that is now waste. 
     Disposing of spent drilling fluid may involve burning the contents in a cement kiln. Some have attempted to recover the oil from the drilling fluid. For example, the spent drilling fluid may be heated in a high temperature calciner to vaporize the fluid that can then be condensed and recovered. However, high temperature processes can be energy intensive and, in some instances, may crack or degrade the oil, which reduces the ability to reuse the oil in a new drilling fluid. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       These drawings illustrate certain aspects of some of the present disclosure, and should not be used to limit or define the disclosure. 
         FIG. 1  illustrates wellbore drilling assembly. 
         FIG. 2  illustrates an embodiment of fluid processing unit. 
         FIG. 3  illustrates an embodiment of a screw. 
         FIG. 4  illustrates an embodiment of a intermeshing co-rotating screw extruder. 
     
    
    
     DETAILED DESCRIPTION 
     The present disclosure may be directed to oil and gas production wells, and, at least in part, to using fluid processing units to “clean” drilling waste fluids. The fluid processing units may utilize thermal desorption to accomplish separation of the drilling waste fluids. Specifically, the present disclosure may utilize a thermal extraction chamber to accomplish separation of the drilling waste fluids. The present disclosure may improve the mass and energy transfer within the thermal extraction chamber by varying the screw geometry. The screw geometry of the present disclosure may provide high mixing capabilities and may require lower revolutions per minute (RPMs) than alternative techniques. The screw geometry may also increase the footprint utilization of the technology by means of achieving higher throughputs. 
       FIG. 1  illustrates wellbore drilling assembly  100 . In an embodiment, drilling fluids may directly or indirectly affect one or more components or pieces of equipment associated with wellbore drilling assembly  100 , according to one or more embodiments. It should be noted that while  FIG. 1  generally depicts a land-based drilling assembly, those skilled in the art will readily recognize that the principles described herein are equally applicable to subsea drilling operations that employ floating or sea-based platforms and rigs, without departing from the scope of the disclosure. 
     As illustrated, the drilling assembly  100  may include a drilling platform  102  that supports a derrick  104  having a traveling block  106  for raising and lowering a drill string  108 . The drill string  108  may include, but is not limited to, drill pipe and coiled tubing, as generally known to those skilled in the art. A kelly  110  supports the drill string  108  as it is lowered through a rotary table  112 . A drill bit  114  may be attached to the distal end of the drill string  108  and is driven either by a downhole motor and/or via rotation of the drill string  108  from the well surface. As the bit  114  rotates, it creates a borehole  116  that penetrates various subterranean formations  118 . 
     A pump  120  (e.g., a mud pump) circulates a drilling fluid  122  through a feed pipe  124  and to the kelly  110 , which conveys the drilling fluid  122  downhole through the interior of the drill string  108  and through one or more orifices in the drill bit  114 . The drilling fluid  122  is then circulated back to the surface via an annulus  126  defined between the drill string  108  and the walls of the borehole  116 . At the surface, the recirculated or spent drilling fluid  122  exits the annulus  126  and may be conveyed to one or more fluid processing unit(s)  128  via an interconnecting flow line  130 . After passing through the fluid processing unit(s)  128 , a “cleaned” drilling fluid  122  is deposited into a nearby retention pit  132  (i.e., a mud pit). While illustrated as being arranged at the outlet of the wellbore  116  via the annulus  126 , those skilled in the art will readily appreciate that the fluid processing unit(s)  128  may be arranged at any other location in the drilling assembly  100  to facilitate its proper function, without departing from the scope of the disclosure. In an embodiment, fluid processing unit(s)  128  may be located off-site at a facility. 
     One or more additional additives may be added to the drilling fluid  122  via a mixing hopper  134  communicably coupled to or otherwise in fluid communication with the retention pit  132 . The mixing hopper  134  may include, but is not limited to, mixers and related mixing equipment known to those skilled in the art. In other embodiments, however, additional additives may be added to the drilling fluid  122  at any other location in the drilling assembly  100 . In at least one embodiment, for example, there could be more than one retention pit  132 , such as multiple retention pits  132  in series. Moreover, the retention pit  132  may be representative of one or more fluid storage facilities and/or units where the additional additives may be stored, reconditioned, and/or regulated until added to the drilling fluid  122 . 
     Certain embodiments of the present disclosure may be implemented at least in part with an information handling system  140 . For purposes of this disclosure, an information handling system  140  may include any instrumentality or aggregate of instrumentalities operable to compute, classify, process, transmit, receive, retrieve, originate, switch, store, display, manifest, detect, record, reproduce, handle, or utilize any form of information, intelligence, or data for business, scientific, control, or other purposes. For example, an information handling system  140  may be a personal computer, a network storage device, or any other suitable device and may vary in size, shape, performance, functionality, and price. The information handling system  140  may include random access memory (RAM), one or more processing resources such as a central processing unit (CPU) or hardware or software control logic, ROM, and/or other types of nonvolatile memory. Additional components of the information handling system  140  may include one or more disk drives, one or more network ports for communication with external devices as well as various input and output (I/O) devices, such as a keyboard, a mouse, and a video display. The information handling system  140  may also include one or more buses operable to transmit communications between the various hardware components. 
     Certain embodiments of the present disclosure may be implemented at least in part with non-transitory computer-readable media. For the purposes of this disclosure, non-transitory computer-readable media may include any instrumentality or aggregation of instrumentalities that may retain data and/or instructions for a period of time. Non-transitory computer-readable media may include, for example, without limitation, storage media such as a direct access storage device (e.g., a hard disk drive or floppy disk drive), a sequential access storage device (e.g., a tape disk drive), compact disk, CD-ROM, DVD, RAM, ROM, electrically erasable programmable read-only memory (EEPROM), and/or flash memory; as well as communications media such wires, optical fibers, microwaves, radio waves, and other electromagnetic and/or optical carriers; and/or any combination of the foregoing. 
     As mentioned above, the drilling fluid  122  prepared with a composition disclosed herein may directly or indirectly affect the components and equipment of the drilling assembly  100 . For example, the disclosed drilling fluid  122  may directly or indirectly affect the fluid processing unit(s)  128  which may include, but is not limited to, one or more of a shaker (e.g., shale shaker), a centrifuge, a cyclone, a separator (including magnetic and electrical separators), a desilter, a desander, a filter (e.g., diatomaceous earth filters), a heat exchanger, any fluid reclamation equipment. The fluid processing unit(s)  128  may further include one or more sensors, gauges, pumps, compressors, and the like used to store, monitor, regulate, and/or recondition the drilling fluid  122 . 
     The drilling fluid  122  may directly or indirectly affect the pump  120 , which representatively includes any conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically convey the drilling fluid  122  downhole, any pumps, compressors, or motors (e.g., topside or downhole) used to drive the drilling fluid  122  into motion, any valves or related joints used to regulate the pressure or flow rate of the drilling fluid  122 , and any sensors (i.e., pressure, temperature, flow rate, etc.), gauges, and/or combinations thereof, and the like. The disclosed drilling fluid  122  may also directly or indirectly affect the mixing hopper  134  and the retention pit  132  and their assorted variations. 
     The drilling fluid  122  may also directly or indirectly affect the various downhole equipment and tools that may come into contact with the drilling fluid  122  such as, but not limited to, the drill string  108 , any floats, drill collars, mud motors, downhole motors and/or pumps associated with the drill string  108 , and any MWD/LWD tools and related telemetry equipment, sensors or distributed sensors associated with the drill string  108 . Drilling fluid  122  may also directly or indirectly affect any downhole heat exchangers, valves and corresponding actuation devices, tool seals, packers and other wellbore isolation devices or components, and the like associated with the wellbore  116 . Drilling fluid  122  may also directly or indirectly affect the drill bit  114 , which may include, but is not limited to, roller cone bits, PDC bits, natural diamond bits, any hole openers, reamers, coring bits, the like, and/or any combination thereof. 
     While not specifically illustrated herein, the drilling fluid  122  may also directly or indirectly affect any transport or delivery equipment used to convey the drilling fluid  122  to the drilling assembly  100  such as, for example, any transport vessels, conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically move the drilling fluid  122  from one location to another, any pumps, compressors, or motors used to drive the drilling fluid  122  into motion, any valves or related joints used to regulate the pressure or flow rate of the drilling fluid  122 , and any sensors (i.e., pressure and temperature), gauges, and/or combinations thereof, and the like. 
       FIG. 2  illustrates an embodiment of fluid processing unit  128 . The fluid processing unit  128  may include a hopper  202  to which the drilling waste fluid  204  may be loaded and mixed (e.g., homogenized). Drilling waste fluid  204  may be any fluid produced from subterranean formation  118  (referring to  FIG. 1 ). Drilling waste fluid  204  may comprise, drilling fluid, cuttings, spent fluids, additives, hydrocarbons, the like, and/or any combination thereof. Hopper  202  feeds the drilling waste fluid  204  at an appropriate rate into a thermal extraction chamber  206 . In an embodiment, drilling waste fluid  204  may not be pretreated before entering thermal extraction chamber  206 . In an embodiment, drilling waste fluid  204  may be pretreated before entering thermal extraction chamber  206 . Any suitable pre-treatment may be used and should not be limited herein. Any suitable thermal extraction chamber  206  capable of conveying, heating, and boiling off material may be used and should not be limited herein. In an embodiment, thermal extraction chamber  206  may operate at a temperature of about 150° C. to about 350° C. In an embodiment, thermal extraction chamber  206  may comprise an external heat source (not shown). Any suitable external heat source capable of operating temperatures of about 400° to about 1,000° C. may be used. Any suitable external heat source may be used and should not be limited herein. In an embodiment, thermal extraction chamber  206  may be a screw extruder. Any suitable screw extruder may be used. In an embodiment, the screw extruder may comprise a screw (referring to  FIG. 3 ) disposed within a barrel (not shown). Optionally, the screw extruder may comprise a plurality of screws. In an embodiment, thermal extraction chamber  206  may be a co-rotating dual screw extruder. Thermal extraction chamber  206  may further comprise a gearbox (not shown) that may be driven by a drive unit  208 . Any suitable drive unit  208  may be used. In an embodiment, drive unit  208  may be a motor. Gearbox (not shown) may be connected to a screw. In an embodiment, gearbox (not shown) may be connected to a screw or a plurality of screws. The thermal extraction chamber  206  may produce evaporated fluid  210 . In an embodiment, evaporated fluid may comprise any suitable components including but not limited to, water, oil, organic materials, inorganic materials, fine solids, the like, and/or any combination thereof. 
     In an embodiment, evaporated fluid  210  may then pass through scrubber  212 . Any suitable scrubber capable of removing fines from evaporated fluid  210  may be used. Suitable scrubbers may include, but are not limited to, filters, cyclones, the like, and/or any combination thereof. In an embodiment, solids collected by scrubber  212  may be collected and stored (not shown). 
     Evaporated fluid  210  may then pass to an oil condenser  214  to recover heavy oil  216 , if present. The evaporated fluid  210  (less heavy oil  216  if removed) may then pass to a steam condenser  218  that separates non-condensable gas  220  (e.g., nitrogen) from a mixture of water and light oil  222 . Any suitable condensers may be used and should not be limited herein. The mixture of water and light oil  222  may then be processed in an separator  224  to produce recovered water  226  and recovered light oil  228 . Solids  230  from the drilling waste fluid may be collected from thermal extraction chamber  206 . In an embodiment, solids  230  may be stored or discarded as is. In some instances (e.g., with fine solids that easily become airborne), water (e.g., recovered water  226 ) or another fluid may be used to hydrate solids  230  in a rehydration unit  232  to produce hydrated solids  234 . In an embodiment, the solids collected by scrubber  212  may be combined with solids  230 . In an embodiment, the solids collected by scrubber  212  may be treated in a similar, but independent, process as solids  230 . 
     In an embodiment, a system may include a programmable logic controller and sensors which may monitor and execute various steps of the methods described herein. For example, a thermal extraction chamber  206  may include sensors for monitoring temperature, which may be used to guide the feed rate of drilling waste fluid  204  into the thermal extraction chamber  206  and the rotational speed of the rotors in the thermal extraction chamber  206 , and the rate at which low gravity solids are removed from the thermal extraction chamber  206 . 
     In some instances, a system, or portion thereof, may be deployed on a truck, a barge (or other water-faring vessel), or the like and travel between well sites or drilling platforms to collect and process drilling waste fluid  204 . Such embodiments may advantageously reduce the space for storage of drilling waste fluid  204 , which may be especially advantageous for off-shore drilling platforms where space is a precious commodity. 
     The thermal extraction chamber  206  (referring to  FIG. 2 ) may comprise screw  300  as described in  FIG. 3 . In an embodiment, thermal extraction chamber  206  may comprise a plurality of screws  300 . Any suitable screw  300  capable of conveying, mixing, and may have an identical intermeshing screw within thermal extraction chamber  206  may be used. Screw  300  may comprise any suitable metal or metal alloy. As used herein, “metal alloy” refers to a mixture of two or more elements, wherein at least one of the elements is a metal. In an embodiment, screw  300  may comprise at least one metal selected from the group consisting of, lithium, sodium, potassium, rubidium, cesium, francium, beryllium, magnesium, calcium, strontium, barium, radium, aluminum, gallium, indium, tin, thallium, lead, bismuth, scandium, titanium, vanadium, chromium, manganese, iron, cobalt, nickel, copper, zinc, yttrium, zirconium, niobium, molybdenum, technetium, ruthenium, rhodium, palladium, silver, cadmium, lanthanum, hafnium, tantalum, tungsten, rhenium, osmium, iridium, platinum, gold, graphite, and combinations thereof. In an embodiment, screw  300  may comprise a hardened steel metal alloy. 
     Screw  300  may comprise any suitable geometry. In an embodiment, the geometry of screw  300  may be selected such that the heating surface area may be maximized while minimizing the amount of revolutions per minute (RPM) required to mix drilling waste fluid  204 . Screw  300  may require any suitable amount of RPMs capable of creating sufficient mixing intensity for the drilling waste fluid  204  and should not be limited herein. In an embodiment, screw  300  may require about 10 RPMs to about 60 RPMs, or about 100 RPMs to about 200 RPMs, and/or any value or range of values therein. In an embodiment, screw  300  may require about 10 to about 200 RPMs so as to mix drilling waste fluid  204 . Screw  300  may comprise any suitable surface area for a given application. Suitable surface areas for a single screw may include, but are not limited to, from about 1 m 2  to about 100 m 2 , and/or any value or range of values therein. In an embodiment, two screws  300  may be used in thermal extraction chamber  206 . The two screws  300  may comprise any suitable combined surface area including but not limited to, about 1 m 2  to about 100 m 2 , or about 1 m 2  to about 50 m 2 , or about 1 m 2  to about 10 m 2 , or any value or range of values therein. Screw  300  may comprise any suitable outer diameter  314  including but not limited to, ranging from about 60 mm to about 1,000 mm, or about 60 mm to about 600 mm, or about 60 mm to about 300 mm, and/or any value or range of values therein. Screw  300  may comprise shaft  302 . In an embodiment, shaft  302  may be solid. Shaft  302  may comprise any suitable diameter  316  including but not limited to, ranging from about 50 mm to about 900 mm, or about 50 mm to about 590 mm, or about 50 mm to about 290 mm, or any value or range of values therein. Shaft  302  may be of any suitable length including but not limited to, ranging from about 10 mm to about 100 mm, or about 10 mm to about 75 mm, or about 10 mm to about 50 mm, or any value or range of values therein. Screw  300  may comprise any suitable Screw  300  may further comprise flite  304 . As used herein, flite  304  may be defined as the helical thread or raised portion of screw  300 . Flite  304  may be any raised portion either partially, completely, or repeatedly turned about shaft  302 . Flite  304  may be of any suitable flite width  306 , including but not limited to, ranging from about 1 mm to about 30 mm, or about 1 mm to about 15 mm, or about 15 mm to about 30 mm. Flite  304  may comprise any suitable flite depth  318 . In an embodiment, flite  304  may comprise a flite depth  318 , including but not limited to, ranging from about 1 mm to about 40 mm, or about 1 mm to about 20 mm, or about 20 mm to about 40 mm, or any value or range of values therein. In an embodiment, flite  304  may comprise any suitable helix angle  320  for a given application. Helix angle  320  as used herein may refer to the angle of flite  304  relative to a plane perpendicular to the screw plane. Suitable helix angle  320  may include but are not limited to, ranging from about 1° to about 180°, or about 1° to about 90°, or about 90° to about 180°, or any value or range of values therein. 
     In an embodiment, screw  300  may comprise a plurality of flites  304  spaced longitudinally about the center axis of screw  300  at a predetermined pitch  308 . Pitch  308  as used herein may be defined as the distance between two consecutive flites  304 . Flites  304  may comprise any suitable pitch  308  including but not limited to, ranging from about 1 mm to about 240 mm, or about 1 mm to about 120 mm, or about 120 mm to about 240 mm, or any value or range of values therein. 
     In an embodiment, a plurality of flites  304  may form flite segments  310 ,  312 . Flite segments  310 ,  312  may comprise any number of flites  304  for a given application and should not be limited herein. Screw  300  may comprise any suitable number of flite segments  310 ,  312  and should not be limited herein. In an embodiment, flite segment  310  and flite segment  312  may comprise varying pitches  308 , flite widths  306 , number of flites  304 , outer diameters  314 , flite depths  318 , shaft diameters  316 , the like, and/or any combination thereof. In an embodiment, flite segment  310  may comprise different parameters and/or characteristics from flite segment  312 . In an embodiment, flite segments  310  and flite segment  312  may comprise the same parameters and/or characteristics. 
     In an embodiment, screw  300  may comprise kneading block  322 . Any suitable kneading block  322  capable of reducing and/or stopping the flow of drilling waste fluid  204  (referring to  FIG. 2 ) through thermal extraction chamber  206  thereby increasing the amount of time the drilling waste fluid remains in the thermal extraction chamber  206  may be used. Kneading block  322  may comprise any suitable metal or metal alloy. In an embodiment, kneading block  322  may comprise at least one metal selected from the group consisting of, lithium, sodium, potassium, rubidium, cesium, francium, beryllium, magnesium, calcium, strontium, barium, radium, aluminum, gallium, indium, tin, thallium, lead, bismuth, scandium, titanium, vanadium, chromium, manganese, iron, cobalt, nickel, copper, zinc, yttrium, zirconium, niobium, molybdenum, technetium, ruthenium, rhodium, palladium, silver, cadmium, lanthanum, hafnium, tantalum, tungsten, rhenium, osmium, iridium, platinum, gold, graphite, and combinations thereof. In an embodiment, kneading block  322  may comprise a hardened steel metal alloy. 
     Kneading block  322  may be of any suitable cross-sectional shape for a given application. In an embodiment, suitable cross-sectional shapes for kneading block  322  may include but are not limited to circle, oval, ellipse, parabola, hyperbola, triangle, square, rectangle, octagon, hexagon, pentagon, trapezium, parallelogram, rhombus, kite, heptagon, nonagon, decagon, four point star, five point star, six point star, heart, crescent, cross, polygon, crescent, the like, and/or any combination thereof. Kneading block  322  may be of any suitable width  324 . Suitable widths may include but are not limited to, ranging from about 2 mm to about 20 mm, or about 1 mm to about 25 mm, or about 1 mm to about 30 mm, or any value or range of values therein. In an embodiment, screw  300  may comprise a plurality of kneading blocks  322  thereby forming a kneading block sequence  326 . 
     Kneading block sequence  326  may be used to aggressively mix drilling waste fluid  204  within thermal extraction chamber  206  (referring to  FIG. 2 ). In an embodiment, the first kneading block  322  in kneading block sequence  326  may begin at any given angle relative to the center axis of screw  300 . Each proceeding kneading block  322  within kneading block sequence  326  may be rotated by an angle relative to the kneading block  322  immediately preceding it until the last kneading block  322  in the sequence may be in the same position as the first kneading block  322  in the kneading block sequence  326 . In other words, each kneading block  322  within the sequence  326  must be rotated by an angle relative to the kneading block  322  immediately preceding until the kneading blocks  322  have rotated 360°. Any suitable angle may be used to produce kneading block sequence  326  and should not be limited herein. In an embodiment, each proceeding kneading block  322  may be rotated by an angle ranging from about 1° to about 360°, about 1° to about 90°, about 90° to about 180°, or about 180° to about 360°, or any angle encompassed therein. In an embodiment, each kneading block  322  may be rotated by about 1°, 15°, 25°, 35°, 45°, 55°, 65°, 75°, 85°, 90°, 95°, 105°, 115°, 125°, 135°, 145°, 155°, 165°, 175°, 185°, 195°, 205°, 215°, 225°, 235°, 245°, 255°, 265°, 275°, 285°, 295°, 305°, 315°, 325°, 335°, 345°, 355°, 360°, the like, and/or any combination thereof. Any suitable number of kneading blocks  322  may be used to complete kneading block sequence  326 . 
     In an embodiment, screw  300  may comprise a non-existent conveying pattern. As used herein, non-existent conveying pattern may be defined as a screw  300  comprising a helix angle of about 90° from the horizontal of the shaft or a screw  300  the may not comprise fliting. Screw  300  may comprise a conveying pattern, a non-existent conveying pattern, and/or any combination thereof. In an embodiment, any percentage of the length of screw  300  may comprise a conveying pattern. In an embodiment, screw  300  may comprise a conveying pattern of about 1% to about 100% of the length of screw  300 , or about 1% to about 50% of the length of screw  300 , or about 50% to about 100% of the length of screw  300 , or any value or range of values therein. In an embodiment, any percentage of the length of screw  300  may comprise a non-existent conveying pattern. In an embodiment, screw  300  may comprise a non-existent conveying pattern of about 1% to about 100% of the length of screw  300 , or about 1% to about 50% of the length of screw  300 , or about 50% to about 100% of the length of screw  300 , or any value or range of values therein. 
     In an embodiment, screw  300  may comprise kneading block sequence  326  and flite segments  310 ,  312 , wherein the kneading block sequences  326  and the flite segments  310 ,  312  are alternating. Screw  300  may comprise any suitable number of kneading block sequences  326  and flite segments  310 ,  312  and should not be limited herein. Kneading block sequences  326  and flite segments  310 ,  312  may be in any suitable configuration and should not be limited herein. Suitable configurations for kneading block sequences  326  and flite segments  310 ,  312  may be include, but are not limited to, random, uniform, block, Kneading block sequences  326  and flite segments  310 ,  312  may be disposed at any location on screw  300 . In an embodiment, kneading block sequences  326  and flite segments  310 ,  312  may be disposed within the first half of screw  300 . In an embodiment, the first half of screw  300  may refer to the portion of the screw closest to the inlet (e.g., closest to the hopper) and may extend longitudinally to about the middle of screw  300 . 
       FIG. 4  illustrates an embodiment of an intermeshing co-rotating screw extruder  400 . In an embodiment, the screws may be positioned such that the flites of a first screw  410  are intermeshing with the flites of a second screw  412 . The first screw  410  and the second screw may be fully intermeshed, partially intermeshed, the like, or any combination thereof. The flites may be intermeshed with each other so that the outer diameter of each flite is spaced a short distance from the opposite screw. In an embodiment, first screw  410  may be positioned alongside second screw  412  such that drilling waste fluid surges between the flites of first screw  410  and second screw  412 . In an embodiment, the profile of first screw  410  may be identical to profile of second screw  412 . In an embodiment, the helix angle of the flites may be adjusted to allow for more thermal contact, thereby increasing the thermal heat transfer per lineal foot. In an embodiment, kneading block segments  402  may be selected so that kneading blocks  322  (referring to  FIG. 3 ) may reduce and/or stop the flow of material (e.g. drilling waste fluid) through co-rotating screw extruder  400 , thereby increasing the amount of time the material may remain co-rotating screw extruder  400 . In an embodiment, this may allow the material to be subjected to high mixing intensity. High mixing intensity may correlate to higher mass and energy transfer which may thereby improve the efficiencies of the process. An increase in the mean flow path of the fluid/particles within the screw may be a direct correlation to mixing intensity. Therefore, the more flights that may be non-conveying within the geometry of the screw, the mixing intensity may be improved. The assembly of the barrel and screws, with suitable bearings, synchronizing gears, and material inlet and outlet diverter plate ports, constitutes a thermal extraction chamber. It should be noted that this embodiment is merely an example of an intermeshing co-rotating screw extruder and should not be limited herein. Any suitable intermeshing co-rotating screw extruder may be used. 
     The exemplary treatment fluid particulates disclosed herein may directly or indirectly affect one or more components or pieces of equipment associated with the preparation, delivery, recapture, recycling, reuse, and/or disposal of the treatment fluid particulates. For example, the treatment fluid particulates may directly or indirectly affect one or more mixers, related mixing equipment, mud pits, storage facilities or units, composition separators, heat exchangers, sensors, gauges, pumps, compressors, and the like used to generate, store, monitor, regulate, and/or recondition the sealant composition. The treatment fluid particulates may also directly or indirectly affect any transport or delivery equipment used to convey the treatment fluid particulates to a well site or downhole such as, for example, any transport vessels, conduits, pipelines, trucks, tubulars, and/or pipes used to compositionally move the treatment fluid particulates from one location to another, any pumps, compressors, or motors (e.g., topside or downhole) used to drive the treatment fluid particulates into motion, any valves or related joints used to regulate the pressure or flow rate of the treatment fluid particulates (or fluids containing the same treatment fluid particulates), and any sensors (i.e., pressure and temperature), gauges, and/or combinations thereof, and the like. The disclosed treatment fluid particulates may also directly or indirectly affect the various downhole equipment and tools that may come into contact with the treatment fluid particulates such as, but not limited to, wellbore casing, wellbore liner, completion string, insert strings, drill string, coiled tubing, slickline, wireline, drill pipe, drill collars, mud motors, downhole motors and/or pumps, cement pumps, surface-mounted motors and/or pumps, centralizers, turbolizers, scratchers, floats (e.g., shoes, collars, valves, etc.), logging tools and related telemetry equipment, actuators (e.g., electromechanical devices, hydromechanical devices, etc.), sliding sleeves, production sleeves, plugs, screens, filters, flow control devices (e.g., inflow control devices, autonomous inflow control devices, outflow control devices, etc.), couplings (e.g., electro-hydraulic wet connect, dry connect, inductive coupler, etc.), control lines (e.g., electrical, fiber optic, hydraulic, etc.), surveillance lines, drill bits and reamers, sensors or distributed sensors, downhole heat exchangers, valves and corresponding actuation devices, tool seals, packers, cement plugs, bridge plugs, and other wellbore isolation devices, or components, and the like. 
     Accordingly, this disclosure describes methods, systems, and apparatuses that may use the disclosed screws. The methods, systems, and apparatuses may include any of the following statements: 
     Statement 1. A method for separating a drilling waste fluid, the method comprising: introducing the drilling waste fluid into a thermal extraction chamber via a hopper; allowing the drilling waste fluid to flow longitudinally along two screws disposed within the thermal extraction chamber, wherein each screw comprises a shaft, a first flite segment, and a first kneading block sequence; allowing the geometry of the screws to separate drilling waste fluid into an evaporated fluid and solids; and removing the evaporated fluid through a first outlet port; removing the solids through a second outlet port. 
     Statement 2. The method of statement 1, wherein the two screws comprise identical profiles. 
     Statement 3. The method of statement 1 or 2, wherein the first flite segment comprises a plurality of flites. 
     Statement 4. The method of any of the preceding statements, wherein each flite comprises a pitch of about 1 mm to about 240 mm. 
     Statement 5. The method of any of the preceding statements, wherein each flite comprises a flite depth of about 1 mm to about 40 mm. 
     Statement 6. The method of any of the preceding statements, wherein each flite comprises a helix angle of about 1° to about 180°. 
     Statement 7. The method of any of the preceding statements, wherein each flite comprises a flite width of about 1 mm to about 30 mm. 
     Statement 8. The method of any of the preceding statements, wherein the first flite segment comprises an outer diameter of about 60 mm to about 1,000 mm. 
     Statement 9. The method of any of the preceding statements, wherein the two screws further comprise a second flite segment, wherein the first flite segment and the second flite segment vary in at least one parameter selected from the group consisting of pitch, flite depth, flite width, helix angle, outer diameter, and any combination thereof. 
     Statement 10. The method of any of the preceding statements, wherein the first kneading block sequence comprises a plurality of kneading blocks. 
     Statement 11. The method of any of the preceding statements, wherein each kneading block comprises a cross-section shape selected from the group consisting of circle, oval, ellipse, parabola, hyperbola, triangle, square, rectangle, octagon, hexagon, pentagon, trapezium, parallelogram, rhombus, kite, heptagon, nonagon, decagon, four point star, five point star, six point star, heart, crescent, cross, polygon, crescent, or any combination thereof. 
     Statement 12. The method of any of the preceding statements, wherein each kneading block is angled relative to each preceding kneading block ranging from about 1° to about 180°. 
     Statement 13. The method of any of the preceding statements, wherein each kneading block comprises a width of about 1 mm to about 20 mm. 
     Statement 14. The method of any of the preceding statements, wherein the two screws further comprise a second kneading block sequence, wherein the first kneading block sequence and the second kneading block sequence vary in a least one parameter selected from the group consisting of cross-sectional shape, width, angle, and any combinations thereof. 
     Statement 15. The method of any of the preceding statements, wherein the two screws comprise identical profiles, wherein the first flite segment comprises a plurality of flites, wherein each flite comprises a pitch of about 1 mm to about 240 mm, wherein each flite comprises a flite depth of 1 mm to about 40 mm, wherein each flite comprises a flite width of about 1 mm to about 30 mm, wherein each flite comprises a helix angle of about 1° to about 180°, wherein the first flite segment comprises an outer diameter of about 60 mm to about 1,000 mm, wherein the first kneading block sequence comprises a plurality of kneading blocks, wherein each kneading block is angled relative to each preceding kneading block by about 1° to about 180°, wherein each kneading block comprises a width of 1 mm to about 20 mm. 
     Statement 16. The method of any any of the preceding statements, wherein the two screws further comprise a second flite segment and a second kneading block sequence, wherein the first flite segment and the second flite segment vary in at least one parameter selected from the group consisting of pitch, flite depth, flite width, helix angle, outer diameter, and any combination thereof, and wherein the first kneading block sequence and the second kneading block sequence vary in at least one parameter selected from the group consisting of cross-sectional shape, width, angle, and any combinations thereof. 
     Statement 17. The method of any of the preceding statements, wherein the two screws are co-rotated. 
     Statement 18. A thermal extraction chamber for separating drilling waste fluids, wherein the thermal extraction chamber comprises: a barrel; a first screw; a second screw, wherein the first screw and the second screw comprise identical profiles, wherein the first screw and the second screw comprise a shaft, a first flight segment, and a first kneading block sequence; an inlet port; a first outlet port; and a second outlet port. 
     Statement 19. The thermal extraction chamber of statement 18, wherein the two screws comprise identical profiles, wherein the first flite segment comprises a plurality of flites, wherein each flite comprises a pitch of about 1 mm to about 240 mm, wherein each flite comprises a flite depth of 1 mm to about 40 mm, wherein each flite comprises a flite width of about 1 mm to about 30 mm, wherein each flite comprises a helix angle of about 1° to about 180°, wherein the first flite segment comprises an outer diameter of about 60 mm to about 1,000 mm, wherein the first kneading block sequence comprises a plurality of kneading blocks, wherein each kneading block is angled relative to each preceding kneading block by about 1° to about 180°, wherein each kneading block comprises a width of 1 mm to about 20 mm. 
     Statement 20. The thermal extraction chamber of statement 18 or 19, wherein the two screws further comprise a second flite segment and a second kneading block sequence, wherein the first flite segment and the second flite segment vary in at least one parameter selected from the group consisting of pitch, flite depth, flite width, helix angle, outer diameter, and any combination thereof, and wherein the first kneading block sequence and the second kneading block sequence vary in at least one parameter selected from the group consisting of cross-sectional shape, width, angle, and any combinations thereof. 
     To facilitate a better understanding of the present disclosure, the following examples of certain aspects of some of the systems and methods are given. In no way should the following examples be read to limit, or define, the entire scope of the disclosure. 
     EXAMPLE 1 
     Screws  300  may comprise any suitable parameters and should not be limited herein. Table 1 provides example parameters for screw  300 . It should be noted that these are merely examples and they should not limit the present disclosure herein. 
     
       
         
           
               
               
               
               
             
               
                 TABLE 1 
               
               
                   
               
               
                   
                 Example 
                 Example 
                 Example 
               
               
                 Parameter 
                 Screw 1 
                 Screw 2 
                 Screw 3 
               
               
                   
               
             
            
               
                 Pitch Length (mm) 
                 5-240 
                 10-175 
                 20-100 
               
               
                 Flight Depth (mm) 
                 1-40  
                 5-30 
                 8-20 
               
               
                 Flight Width (mm) 
                 1-20  
                 2-15 
                 3-10 
               
               
                 Helical angle of flight (degrees) 
                 0-90  
                 0-90 
                 0-90 
               
               
                 Conveying or non-conveying 
                 0%- 
                 10%- 
                 20%- 
               
               
                 section (% of screw length) 
                 100% 
                 90% 
                 80% 
               
               
                 Fully intermeshing or partially 
                 0%- 
                 10%- 
                 20%- 
               
               
                 intermeshing (% of screw length) 
                 100% 
                 90% 
                 80% 
               
               
                 Number of flights per pitch (mm) 
                 1-100 
                 1-50 
                 1-2  
               
               
                   
               
            
           
         
       
     
     It should be understood that the compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the element that it introduces. 
     For the sake of brevity, only certain ranges are explicitly disclosed herein. However, ranges from any lower limit may be combined with any upper limit to recite a range not explicitly recited, as well as, ranges from any lower limit may be combined with any other lower limit to recite a range not explicitly recited, in the same way, ranges from any upper limit may be combined with any other upper limit to recite a range not explicitly recited. Additionally, whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values even if not explicitly recited. Thus, every point or individual value may serve as its own lower or upper limit combined with any other point or individual value or any other lower or upper limit, to recite a range not explicitly recited. 
     Therefore, the present disclosure is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular examples disclosed above are illustrative only, as the present disclosure may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Although individual examples are discussed, the disclosure covers all combinations of all those examples. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. It is therefore evident that the particular illustrative examples disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present disclosure. If there is any conflict in the usages of a word or term in this specification and one or more patent(s) or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted.