nf-500 mud pump free sample

Cylinders are made of forged alloy steel. Three cylinders of each pump are interchangeable. Valve-over-valve (through type cylinder) design reduces the cylinder volume and promotes the volumetric efficiency. At customers’ request, the cylinder surface may be nickel plated to improve the abrasion resistance.

The 2,200-hp mud pump for offshore applications is a single-acting reciprocating triplex mud pump designed for high fluid flow rates, even at low operating speeds, and with a long stroke design. These features reduce the number of load reversals in critical components and increase the life of fluid end parts.

The pump’s critical components are strategically placed to make maintenance and inspection far easier and safer. The two-piece, quick-release piston rod lets you remove the piston without disturbing the liner, minimizing downtime when you’re replacing fluid parts.

[0001] In oilfield operations, surfactants can be used in drilling for a variety of functions such as lubrication, enhancement of wetting, corrosion control, and foaming. For example, when used in water-based drilling muds, surfactants can help to control or avoid accumulation of clays on the bit and drill-string, which can cause undesirable "bit-balling." Surfactants can provide a coating on the clay or on the drilling string or drill bit, reducing or eliminating accumulation of sticky clays.

[0031] As used herein, the term "drilling fluid" refers to fluids, slurries, or muds used in drilling operations downhole, such as during the formation of the wellbore.

[0035] As used herein, the term "spotting fluid" refers to fluids or slurries used downhole during spotting operations, and can be any fluid designed for localized treatment of a downhole region. In one example, a spotting fluid can include a lost circulation material for treatment of a specific section of the wellbore, such as to seal off fractures in the wellbore and prevent sag. In another example, a spotting fluid can include a water control material. In some examples, a spotting fluid can be designed to free a stuck piece of drilling or extraction equipment, can reduce torque and drag with drilling lubricants, prevent differential sticking, promote wellbore stability, and can help to control mud weight.

[0058] In some embodiments, the method can be a method of drilling. The method can further include performing a drilling operation after placing the composition in the subterranean formation. The composition can include a drilling fluid; the composition can be a drilling fluid. The drilling fluid can be an aqueous drilling fluid. Obtaining or providing the composition can include obtaining or providing a drilling fluid, and combining the hydroxy-terminated poly(alkylene oxide) copolymer surfactant with the drilling fluid, to provide the composition. Placing the composition in the subterranean formation can include pumping the composition into a drill-string disposed in a wellbore, the drill-string including a drill bit at a downhole end of the drill-string. The method can further include circulating the drilling fluid composition through the drill-string, through the drill bit, and back above- surface through an annulus between the drill-string and the wellbore. The method can further include processing the composition exiting the annulus with at least one fluid processing unit to generate a cleaned composition and recirculating the cleaned composition through the wellbore

providing the composition can include obtaining or providing a fracturing fluid and combining the hydroxy-terminated poly(alkylene oxide) copolymer surfactant with the fracturing fluid, to provide the composition. Placing the composition in the subterranean formation can include pumping the composition into the subterranean formation via a tubular.

[0086] A drilling fluid, also known as a drilling mud or simply "mud," is a specially designed fluid that is circulated through a wellbore as the wellbore is being drilled to facilitate the drilling operation. The drilling fluid can be water-based or oil-based. The drilling fluid can carry cuttings up from beneath and around the bit, transport them up the annulus, and allow their separation. Also, a drilling fluid can cool and lubricate the drill head as well as reduce friction between the drill-string and the sides of the hole. The drilling fluid aids in support of the drill pipe and drill head, and provides a hydrostatic head to maintain the integrity of the wellbore walls and prevent well blowouts. Specific drilling fluid systems can be selected to optimize a drilling operation in accordance with the characteristics of a particular geological formation. The drilling fluid can be formulated to prevent unwanted influxes of formation fluids from permeable rocks and also to form a thin, low permeability filter cake that temporarily seals pores, other openings, and formations penetrated by the bit. In water-based drilling fluids, solid particles are suspended in a water or brine solution containing other components. Oils or other non-aqueous liquids can be emulsified in the water or brine or at least partially solubilized (for less hydrophobic non-aqueous liquids), but water is the continuous phase. The drilling fluid can be present in a composition including the copolymer surfactant in any suitable amount, such as about 1 wt% or less, about 2 wt%, 3, 4, 5, 10, 15, 20, 30, 40, 50, 60, 70, 80, 85, 90, 95, 96, 97, 98, 99, 99.9, 99.99, 99.999, or about 99.9999 wt% or more of the composition.

[0088] An oil-based drilling fluid or mud in embodiments of the present invention can be any suitable oil-based drilling fluid. In various embodiments the drilling fluid can include at least one of an oil-based fluid (or synthetic fluid), saline, aqueous solution, emulsifiers, other agents of additives for suspension control, weight or density control, oil- wetting agents, fluid loss or filtration control agents, and rheology control agents. For example, see H. C. H. Darley and George R. Gray, Composition and Properties of Drilling and Completion Fluids 66-67, 561-562 (5th ed. 1988). An oil-based or invert emulsion-based drilling fluid can include between about 10:90 to about 95:5, or about 50:50 to about 95:5, by volume of oil phase to water phase. A substantially all oil mud includes about 100% liquid phase oil by volume (e.g., substantially no internal aqueous phase).

[0095] A pump 120 (e.g., a mud pump) circulates drilling fluid 122 through a feed pipe 124 and to the kelly 1 10, 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 1 14. 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 wellbore 1 16. 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 (e.g., a mud pit). While illustrated as being arranged at the outlet of the wellbore 1 16 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.

hydrocyclone, a separator (including magnetic and electrical separators), a desilter, a desander, a separator, a filter (e.g., diatomaceous earth filters), a heat exchanger, or 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 composition including the copolymer surfactant.

[0098] The copolymer surfactant or a composition including the copolymer surfactant may directly or indirectly affect the pump 120, which representatively includes any conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically convey the composition including the copolymer surfactant downhole, any pumps, compressors, or motors (e.g., topside or downhole) used to drive the composition into motion, any valves or related joints used to regulate the pressure or flow rate of the composition, and any sensors (e.g., pressure, temperature, flow rate, and the like), gauges, and/or combinations thereof, and the like. The copolymer surfactant or a composition including the copolymer surfactant may also directly or indirectly affect the mixing hopper 134 and the retention pit 132 and their assorted variations.

[0099] The copolymer surfactant or a composition including the copolymer surfactant may also directly or indirectly affect the various downhole equipment and tools that may come into contact with the copolymer surfactant or a composition including the copolymer surfactant 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 measurement while drilling (MWD)/logging while drilling (LWD) tools and related telemetry equipment, sensors, or distributed sensors associated with the drill-string 108. The copolymer surfactant or a composition including the copolymer surfactant 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. The copolymer surfactant or a composition including the copolymer surfactant may also directly or indirectly affect the drill bit 1 14, which may include, but is not limited to, roller cone bits, polycrystalline diamond compact (PDC) bits, natural diamond bits, any hole openers, reamers, coring bits, and the like.

the copolymer surfactant from one location to another, any pumps, compressors, or motors used to drive the composition into motion, any valves or related joints used to regulate the pressure or flow rate of the composition, and any sensors (e.g., pressure and temperature), gauges, and/or combinations thereof, and the like.

[00103] Various embodiments provide systems and apparatus configured for delivering the composition described herein to a downhole location and for using the composition therein, such as for drilling or hydraulic fracturing. The system or apparatus can include a drill-string disposed in a wellbore, the drill-string including a drill bit at the downhole end of the drill-string. The system or apparatus can include an annulus between the drill-string and the wellbore. The system or apparatus can include a pump configured to circulate the composition through the drill-string, through the drill bit, and back above-surface through the annulus. The system or apparatus can further include a fluid processing unit configured to process the composition exiting the annulus to generate a cleaned drilling fluid for recirculation through the wellbore. In various embodiments, the systems can include a pump fluidly coupled to a tubular (e.g., any suitable type of oilfield pipe, such as pipeline, drill pipe, production tubing, and the like), the tubular containing a composition including the copolymer surfactant described herein. The tubular can be disposed in a wellbore. The pump can be configured to pump the composition downhole.

[00104] The pump can be a high pressure pump in some embodiments. As used herein, the term "high pressure pump" will refer to a pump that is capable of delivering a fluid downhole at a pressure of about 1000 psi or greater. A high pressure pump can be used when it is desired to introduce the composition to a subterranean formation at or above a fracture gradient of the subterranean formation, but it can also be used in cases where fracturing is not desired. In some embodiments, the high pressure pump can be capable of fluidly conveying particulate matter, such as proppant particulates, into the subterranean formation. Suitable high pressure pumps will be known to one having ordinary skill in the art and can include, but are not limited to, floating piston pumps and positive displacement pumps.

[00105] In other embodiments, the pump can be a low pressure pump. As used herein, the term "low pressure pump" will refer to a pump that operates at a pressure of about 1000 psi or less. In some embodiments, a low pressure pump can be fluidly coupled to a high pressure pump that is fluidly coupled to the tubular. That is, in such embodiments, the low pressure pump can be configured to convey the composition to the high pressure pump. In such embodiments, the low pressure pump can "step up" the pressure of the composition before it reaches the high pressure pump.

[00106] In some embodiments, the systems or apparatuses described herein can further include a mixing tank that is upstream of the pump and in which the composition is formulated. In various embodiments, the pump (e.g., a low pressure pump, a high pressure pump, or a combination thereof) can convey the composition from the mixing tank or other source of the composition to the tubular. In other embodiments, however, the composition can be formulated offsite and transported to a worksite, in which case the composition can be introduced to the tubular via the pump directly from its shipping container (e.g., a truck, a railcar, a barge, or the like) or from a transport pipeline. In either case, the composition can be drawn into the pump, elevated to an appropriate pressure, and then introduced into the tubular for delivery downhole.

composition can be formulated. The composition can be conveyed via line 12 to wellhead 14, where the composition enters tubular 16, with tubular 16 extending from wellhead 14 into subterranean formation 18. Upon being ejected from tubular 16, the composition can subsequently penetrate into subterranean formation 18. Pump 20 can be configured to raise the pressure of the composition to a desired degree before its introduction into tubular 16. It is to be recognized that system or apparatus 1 is merely exemplary in nature and various additional components can be present that have not necessarily been depicted in FIG. 2 in the interest of clarity. Non-limiting additional components that can be present include, but are not limited to, supply hoppers, valves, condensers, adapters, joints, gauges, sensors, compressors, pressure controllers, pressure sensors, flow rate controllers, flow rate sensors, temperature sensors, and the like.

[00109] It is also to be recognized that the disclosed copolymer surfactant and composition including the same can also directly or indirectly affect the various downhole equipment and tools that can come into contact with the composition during operation. Such equipment and tools can include, but are 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, surface-mounted motors and/or pumps, centralizers, turbolizers, scratchers, floats (e.g., shoes, collars, valves, and the like), logging tools and related telemetry equipment, actuators (e.g., electromechanical devices, hydromechanical devices, and the like), sliding sleeves, production sleeves, plugs, screens, filters, flow control devices (e.g., inflow control devices, autonomous inflow control devices, outflow control devices, and the like), couplings (e.g., electro-hydraulic wet connect, dry connect, inductive coupler, and the like), control lines (e.g., electrical, fiber optic, hydraulic, and the like), 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

[00128] Embodiment 14 provides the method of any one of Embodiments 1 - 13, wherein placing the composition in the subterranean formation comprises pumping the composition into a drill-string disposed in a wellbore, the drill-string comprising a drill bit at a downhole end of the drill-string.

[00136] Embodiment 22 provides the method of any one of Embodiments 1-21, wherein placing the composition in the subterranean formation comprises pumping the composition into the subterranean formation via a tubular, the method further comprising fracturing the subterranean formation.

[00202] Embodiment 88 provides the system of any one of Embodiments 85-87, further comprising a tubular disposed in a wellbore; and a pump configured to pump the composition downhole.