Patent Grant
10947967
Not applicable.
Not applicable.
The present disclosure relates generally to a method and apparatus for supplying pressurized fluids. More particularly, the present disclosure relates to methods and reciprocating devices for pumping fluids into a wellbore.
High-pressure pumps having reciprocating elements such as plungers or pistons are commonly employed in oil and gas production fields for operations such as drilling and well servicing. For instance, one or more reciprocating pumps may be employed to pump fluids into a wellbore in conjunction with activities including fracturing, acidizing, remediation, cementing, and other stimulation or servicing activities. Due to the harsh conditions associated with such activities, many considerations are generally taken into account when designing a pump for use in oil and gas operations. Such design considerations may concern the ability to rapidly cease pumping of fluids by the pump and/or the ability to pump fluids into a formation in a pulsed pressure manner.
Accordingly, it is desirable to provide a pump fluid end that enables for rapid disablement of the pump and/or the pumping of fluids in a manner that subjects a formation to pulsating pressures.
For a more complete understanding of this disclosure, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description, wherein like reference numerals represent like parts.
It should be understood at the outset that although an illustrative implementation of one or more embodiments are provided below, the disclosed systems and/or methods may be implemented using any number of techniques, whether currently known or in existence. The disclosure should in no way be limited to the illustrative implementations, drawings, and techniques illustrated below, including the exemplary designs and implementations illustrated and described herein, but may be modified within the scope of the appended claims along with their full scope of equivalents.
A descriptor numeral can be utilized generically herein to refer to any embodiment of that component. For example, generic reference to a “controllable holding system (CHS) 90” can indicate any suitable CHS 90, such as electromagnetically actuatable controllable holding system 90A, as depicted in
Disclosed herein is a reciprocating apparatus for pumping pressurized fluid. In embodiments, the reciprocating apparatus comprises a pump fluid end containing a discharge valve assembly configured to control fluid flow out of a chamber of the pump fluid end of the pump. The discharge valve assembly comprises a controllable holding system (CHS) that is controllable to hold the discharge valve assembly in an open configuration. In embodiments, the reciprocating apparatus is a high-pressure pump configured to operate at a pressure greater than or equal to about 3,000 psi and/or in a well servicing operation and environment. As detailed further hereinbelow, utilization of a discharge valve assembly of this disclosure can enable rapid disablement of the pump, whereby pumping of fluids is ceased, and/or can provide for the pumping of fluids into a formation in a manner that subjects the formation to pulsating pressures.
A reciprocating apparatus of this disclosure may comprise any suitable pump operable to pump fluid. Non-limiting examples of suitable pumps include, but are not limited to, piston pumps, plunger pumps, and the like. In embodiments, the pump is a rotary- or reciprocating-type pump such as a positive displacement pump operable to displace pressurized fluid. The pump comprises a pump power end, a pump fluid end, and an integration section whereby a reciprocating element (e.g., a plunger) can be mechanically connected with the pump power end such that the reciprocating element can be reciprocated within a reciprocating element bore of the pump fluid end.
The pump fluid end 22 is integrated with the pump power end 12 via the integration section 11, such that pump power end 12 is operable to reciprocate the reciprocating element 18 within a reciprocating element bore 24 (
The pump 10 may comprise any suitable pump power end 12 for enabling the pump 10 to perform pumping operations (e.g., pumping a wellbore servicing fluid downhole). Similarly, the pump 10 may include any suitable housing 14 for containing and/or supporting the pump power end 12 and components thereof. The housing 14 may comprise various combinations of inlets, outlets, channels, and the like for circulating and/or transferring fluid. Additionally, the housing 14 may include connections to other components and/or systems, such as, but not limited to, pipes, tanks, drive mechanisms, etc. Furthermore, the housing 14 may be configured with cover plates or entryways for permitting access to the pump power end 12 and/or other pump components. As such, the pump 10 may be inspected to determine whether parts need to be repaired or replaced. The pump power end may also be hydraulically driven, whether it is a non-intensifying or an intensifying system.
Those versed in the art will understand that the pump power end 12 may include various components commonly employed in pumps. Pump power end 12 can be any suitable pump known in the art and with the help of this disclosure to be operable to reciprocate reciprocating element 18 in reciprocating element bore 24. For example, without limitation, pump power end 12 can be operable via and comprise a crank and slider mechanism, a powered hydraulic/pneumatic/steam cylinder mechanism or various electric, mechanical or electro-mechanical drives.
Of course, numerous other components associated with the pump power end 12 of the pump 10 may be similarly employed, and therefore, fall within the purview of the present disclosure. Furthermore, since the construction and operation of components associated with pumps of the sort depicted in
As noted hereinabove, the pump 10 comprises a pump fluid end 22 attached to the pump power end 12. Various embodiments of the pump fluid end 22 are described in detail below in connection with other drawings, for example
In embodiments, the pump fluid end 22 may comprise a cylinder wall 26 at least partially defining a bore 24 through which the reciprocating element 18 may extend and retract. Additionally, the bore 24 may be in fluid communication with a discharge chamber 53 formed within the pump fluid end 22. Such a discharge chamber 53, for example, may be configured as a pressurized discharge chamber 53 having a discharge outlet 54 through which fluid is discharged by the reciprocating element 18. Thus, the reciprocating element 18 may be movably disposed within the reciprocating element bore 24, which may provide a fluid flow path into and/or out of the pump chamber. During operation of the pump 10, the reciprocating element 18 may be configured to reciprocate along a path (e.g., along central axis 17 within bore 24 and/or pump chamber 28, which corresponds to reciprocal movement parallel to the x-axis of
In operation, the reciprocating element 18 extends and retracts along a flow path to alternate between providing forward strokes (also referred to as discharge strokes and correlating to movement in a positive direction parallel to the x-axis of
During a return stroke, the reciprocating element 18 reciprocates or retracts away from the pump fluid end 22 and towards the pump power end 12 of the pump 10. Before the return stroke begins, the reciprocating element 18 is in a fully extended position (also referred to as top dead center (TDC) with reference to the crankshaft 16), in which case the discharge valve assembly 72 can be in a closed configuration having allowed fluid to flow out of the pump chamber 28 and the suction valve assembly 56 is in a closed configuration. When the reciprocating element 18 begins and retracts towards the pump power end 12, the discharge valve assembly 72 assumes a closed configuration, while the suction valve assembly 56 opens. As the reciprocating element 18 moves away from the discharge valve 72 during a return stroke, fluid flows through the suction valve assembly 56 and into the pump chamber 28.
With reference to the embodiments of
With reference to the embodiment of
With reference to the embodiment of
A pump 10 of this disclosure can comprise one or more access ports. For example, with reference to the cross-bore fluid end body 8 embodiments of
In embodiments, a pump fluid end 22 and pump 10 of this disclosure comprise at least one access port located on a side of the discharge valve assembly 72 opposite the suction valve assembly 56. For example, in the cross-bore pump fluid end 22 embodiment of
In embodiments, one or more seals 29 (e.g., “o-ring” seals, packing seals, or the like), also referred to herein as ‘primary’ reciprocating element packing 29 (or “packing 29”) may be arranged around the reciprocating element 18 to provide sealing between the outer walls of the reciprocating element 18 and the inner walls 26 defining at least a portion of the reciprocating element bore 24. The inner walls 26 may be provided by fluid end body 8 or a sleeve within reciprocating element bore 24, as described below. In some concentric bore fluid end designs, a second set of seals (also referred to herein as ‘secondary’ reciprocating element packing; not shown in the Figures) may be fixedly arranged around the reciprocating element 18 to provide sealing between the outer walls of the reciprocating element 18 and the inner walls of a low-pressure cylinder that defines the low pressure chamber described hereinabove (e.g., wherein the secondary packing is farther back along the x-axis and delineates a back end of the low pressure chamber that extends from the primary packing 29 to the secondary packing). In embodiments, only a primary reciprocating element packing is utilized, as fluid enters tail end 62 of reciprocating element 18 without first contacting an outer peripheral wall thereof (i.e., no secondary reciprocating element packing is needed/utilized, because no low pressure chamber external to reciprocating element 18 is utilized). Skilled artisans will recognize that the seals may comprise any suitable type of seals, and the selection of seals may depend on various factors e.g., fluid, temperature, pressure, etc.
While the foregoing discussion focused on a pump fluid end 22 comprising a single reciprocating element 18 disposed in a single reciprocating element bore 24, it is to be understood that the pump fluid end 22 may include any suitable number of reciprocating elements. As discussed further below, for example, the pump 10 may comprise a plurality of reciprocating elements 18 and associated reciprocating element bores 24 arranged in parallel and spaced apart along the z-axis of
Reciprocating element bore 24 can have an inner diameter slightly greater than the outer diameter of the reciprocating element 18, such that the reciprocating element 18 may sufficiently reciprocate within reciprocating element bore 24 (optionally, within a sleeve, as described hereinbelow). In embodiments, the fluid end body 8 of pump fluid end 22 has a pressure rating ranging from about 100 psi to about 3000 psi, or from about 2000 psi to about 10,000 psi, from about 5000 psi to about 30,000 psi, or from about 3000 psi to about 50,000 psi or greater. The fluid end body 8 of pump fluid end 22 may be cast, forged, machined, printed or formed from any suitable materials, e.g., steel, metal alloys, or the like. Those versed in the art will recognize that the type and condition of material(s) suitable for the fluid end body 8 may be selected based on various factors. In a wellbore servicing operation, for example, the selection of a material may depend on flow rates, pressure rates, wellbore service fluid types (e.g., particulate type and/or concentration present in particle laden fluids such as fracturing fluids or drilling fluids, or fluids comprising cryogenic/foams), etc. Moreover, the fluid end body 8 (e.g., cylinder wall 26 defining at least a portion of reciprocating element bore 24 and/or pump chamber 28) may include protective coatings for preventing and/or resisting abrasion, erosion, and/or corrosion.
In embodiments, the cylindrical shape (e.g., providing cylindrical wall(s) 26) of the fluid end body 8 may be pre-stressed in an initial compression. Moreover, a high-pressure cylinder(s) providing the cylindrical shape (e.g., providing cylindrical wall(s) 26) may comprise one or more sleeves (e.g., heat-shrinkable sleeves). Additionally or alternatively, the high-pressure cylinder(s) may comprise one or more composite overwraps and/or concentric sleeves (“over-sleeves”), such that an outer wrap/sleeve pre-loads an inner wrap/sleeve. The overwraps and/or over-sleeves may be non-metallic (e.g., fiber windings) and/or constructed from relatively lightweight materials. Overwraps and/or over-sleeves may be added to increase fatigue strength and overall reinforcement of the components.
The cylinders and cylindrical-shaped components (e.g., providing cylindrical wall 26) associated with the pump fluid end body 8 of pump fluid end 22 may be held in place within the pump 10 using any appropriate technique. For example, components may be assembled and connected, e.g., bolted, welded, etc. Additionally or alternatively, cylinders may be press-fit (e.g., interference fit) into openings machined or cast into the pump fluid end 22 or other suitable portion of the pump 10. Such openings may be configured to accept and rigidly hold cylinders (e.g., having cylinder wall(s) 26 at least partially defining reciprocating element bore 24) in place so as to facilitate interaction of the reciprocating element 18 and other components associated with the pump 10.
In embodiments, the reciprocating element 18 comprises a plunger or a piston. While the reciprocating element 18 may be described herein with respect to embodiments comprising a plunger, it is to be understood that the reciprocating element 18 may comprise any suitable component for displacing fluid. In a non-limiting example, the reciprocating element 18 may be a piston. As those versed in the art will readily appreciate, a piston-type pump generally employs sealing elements (e.g., rings, packing, etc.) attached to the piston and movable therewith. In contrast, a plunger-type pump generally employs fixed or static seals (e.g., primary seal or packing 29) through which the plunger moves during each stroke (e.g., suction stroke or discharge stroke).
As skilled artisans will understand, the reciprocating element 18 may include any suitable size and/or shape for extending and retracting along a flow path within the pump fluid end 22. For instance, reciprocating element 18 may comprise a generally cylindrical shape, and may be sized such that the reciprocating element 18 can sufficiently slide against or otherwise interact with the inner cylinder wall 26. In embodiments, one or more additional components or mechanical linkages 48 (
In some embodiments (e.g., cross-bore pump fluid end 22 embodiments such as
The reciprocating element 18 comprises a front or free end 60. In embodiments comprising concentric bore pump fluid end designs 22 such as shown in
As noted above, pump fluid end 22 contains a suction valve assembly 56. Suction valve assembly 56 may alternately open or close to permit or prevent fluid flow. Skilled artisans will understand that the suction valve assembly 56 may be of any suitable type or configuration (e.g., gravity- or spring-biased, flow activated, etc.). Those versed in the art will understand that the suction valve assembly 56 may be disposed within the pump fluid end 22 at any suitable location therein. For instance, the suction valve assembly 56 may be disposed within the bore 25 below central axis 17 of the pump fluid end 22, in cross-bore pump fluid end 22 designs such as
Pump 10 comprises a discharge valve assembly 72 for controlling the output of fluid through discharge chamber 53 and discharge outlet 54. Analogous to the suction valve assembly 56, the discharge valve assembly 72 may alternately open or close to permit or prevent fluid flow. Those versed in the art will understand that the discharge valve assembly 72 may be disposed within the pump chamber at any suitable location therein. For instance, the discharge valve assembly 72 may be disposed within the bore 25 proximal the top S3 of the pump fluid end 22, in cross-bore pump fluid end 22 designs such as
Further, the suction valve assembly 56 and the discharge valve assembly 72 can comprise any suitable mechanism for opening and closing valves. For example, the suction valve assembly 56 and the discharge valve assembly 72 can comprise a suction valve spring and a discharge valve spring, respectively. Additionally, any suitable structure (e.g., valve assembly comprising sealing rings, stems, valve guides, poppets, etc.) and/or components may be employed for retaining the components of the suction valve assembly 56 and the components of the discharge valve assembly 72 within the pump fluid end 22. For example, the discharge valve assembly 72 and/or the suction valve assembly 56 can comprise a valve poppet, as described, for example, in U.S. patent application Ser. No. 16/436,356 filed Jun. 10, 2019 and entitled “Multi-Material Frac Valve Poppet”, the disclosure of which is hereby incorporated herein in its entirety for purposes not contrary to this disclosure. The suction valve assembly 56 can comprise a suction valve seat and a suction valve body, and/or the discharge valve assembly 72 can comprise a discharge valve seat and a discharge valve body. The suction valve body and the discharge valve body can be any known valve bodies, for example, movable valve poppets, and can be wing guided and/or stem guided, or a combination thereof.
The fluid inlet 38 may be arranged within any suitable portion of the pump fluid end 22 and configured to supply fluid to the pump in any direction and/or angle. Moreover, the pump fluid end 22 may comprise and/or be coupled to any suitable conduit (e.g., pipe, tubing, or the like) through which a fluid source may supply fluid to the fluid inlet 38. The pump 10 may comprise and/or be coupled to any suitable fluid source for supplying fluid to the pump via the fluid inlet 38. In embodiments, the pump 10 may also comprise and/or be coupled to a pressure source such as a boost pump (e.g., a suction boost pump) fluidly connected to the pump 10 (e.g., via inlet 38) and operable to increase or “boost” the pressure of fluid introduced to pump 10 via fluid inlet 38. A boost pump may comprise any suitable type including, but not limited to, a centrifugal pump, a gear pump, a screw pump, a roller pump, a scroll pump, a piston/plunger pump, or any combination thereof. For instance, the pump 10 may comprise and/or be coupled to a boost pump known to operate efficiently in high-volume operations and/or may allow the pumping rate therefrom to be adjusted. Skilled artisans will readily appreciate that the amount of added pressure may depend and/or vary based on factors such as operating conditions, application requirements, etc. In one aspect, the boost pump may have an outlet pressure greater than or equal to about 70 psi, about 80 psi, or about 110 psi, providing fluid to the suction side of pump 10 at about said pressures. Additionally or alternatively, the boost pump may have a flow rate of greater than or equal to about 80 BPM, about 70 BPM, and/or about 50 BPM.
As noted hereinabove, the pump 10 may be implemented as a multi-cylinder pump comprising multiple cylindrical reciprocating element bores 24 and corresponding components. In embodiments, the pump 10 is a Triplex pump in which the pump fluid end 22 comprises three reciprocating assemblies, each reciprocating assembly comprising a suction valve assembly 56, a discharge valve assembly 72, a pump chamber 28, a fluid inlet 38, a discharge outlet 54, and a reciprocating element bore 24 within which a corresponding reciprocating element 18 reciprocates during operation of the pump 10 via connection therewith to a (e.g., common) pump power end 12. In embodiments, the pump 10 is a Quintuplex pump in which the pump fluid end 22 comprises five reciprocating assemblies. In a non-limiting example, the pump 10 may be a Q-10™ Quintuplex Pump or an HT-400™ Triplex Pump, produced by Halliburton Energy Services, Inc.
In embodiments, the pump fluid end 22 may comprise an external manifold (e.g., a suction header) for feeding fluid to the multiple reciprocating assemblies via any suitable inlet(s). Additionally or alternatively, the pump fluid end 22 may comprise separate conduits such as hoses fluidly connected to separate inlets for inputting fluid to each reciprocating assembly. Of course, numerous other variations may be similarly employed, and therefore, fall within the scope of the present disclosure.
Those skilled in the art will understand that the reciprocating elements of each of the reciprocating assemblies may be operatively connected to the pump power end 12 of the pump 10 according to any suitable manner. For instance, separate connectors (e.g., cranks arms/connecting rods 20, one or more additional components or mechanical linkages 48, pushrods 9, etc.) associated with the pump power end 12 may be coupled to each reciprocating element body or tail end 62. The pump 10 may employ a common crankshaft (e.g., crankshaft 16) or separate crankshafts to drive the multiple reciprocating elements.
As previously discussed, the fluid inlet(s) 38 may receive a supply of fluid from any suitable fluid source, which may be configured to provide a constant fluid supply. Additionally or alternatively, the pressure of supplied fluid may be increased by adding pressure (e.g., boost pressure) as described previously. In embodiments, the fluid inlet(s) 38 receive a supply of pressurized fluid comprising a pressure ranging from about 30 psi to about 300 psi.
Additionally or alternatively, the one or more discharge outlet(s) 54 may be fluidly connected to a common collection point such as a sump or distribution manifold, which may be configured to collect fluids flowing out of the fluid outlet(s) 54, or another cylinder bank and/or one or more additional pumps.
During pumping, the multiple reciprocating elements 18 will perform forward and returns strokes similarly, as described hereinabove. In embodiments, the multiple reciprocating elements 18 can be angularly offset to ensure that no two reciprocating elements are located at the same position along their respective stroke paths (i.e., the plungers are “out of phase”). For example, the reciprocating elements may be angularly distributed to have a certain offset (e.g., 120 degrees of separation in a Triplex pump) to minimize undesirable effects that may result from multiple reciprocating elements of a single pump simultaneously producing pressure pulses. The position of a reciprocating element is generally based on the number of degrees a pump crankshaft (e.g., crankshaft 16) has rotated from a bottom dead center (BDC) position. The BDC position corresponds to the position of a fully retracted reciprocating element at zero velocity, e.g., just prior to a reciprocating element moving (i.e., in a direction indicated by arrow 117 in
As described above, each reciprocating element 18 is operable to draw in fluid during a suction (backward or return) stroke and discharge fluid during a discharge (forward) stroke. Skilled artisans will understand that the multiple reciprocating elements 18 may be angularly offset or phase-shifted to improve fluid intake for each reciprocating element 18. For instance, a phase degree offset (at 360 degrees divided by the number of reciprocating elements) may be employed to ensure the multiple reciprocating elements 18 receive fluid and/or a certain quantity of fluid at all times of operation. In one implementation, the three reciprocating elements 18 of a Triplex pump may be phase-shifted by a 120-degree offset. Accordingly, when one reciprocating element 18 is at its maximum forward stroke position, a second reciprocating element 18 will be 60 degrees through its discharge stroke from BDC, and a third reciprocating element will be 120 degrees through its suction stroke from top dead center (TDC).
Herein disclosed is a discharge valve assembly 72 configured to control fluid flow out of a chamber 28 of a pump fluid end 22 of a pump 10. The discharge valve assembly 72 of this disclosure comprises a controllable holding system (CHS) 90 that is controllable to hold the discharge valve assembly 72 in an open configuration (e.g., a discharge valve assembly 72 configuration which allows fluid flow through the discharge valve assembly 72). As described further hereinbelow, the CHS 90 can be electromagnetically, hydraulically, and/or mechanically actuatable. The CHS 90 can comprise a discharge valve arrestor 81, as described hereinbelow.
A discharge valve assembly of this disclosure can be a poppet-type valve assembly or a rotary-type valve assembly. A poppet style valve assembly comprises a poppet (also referred to herein as a “valve”) that moves away from and toward a valve seat to assume an open configuration and a closed configuration, respectively, of the poppet style valve assembly. A rotary type valve assembly comprises a valve body that rotates within a valve seat to assume an open configuration and a closed configuration, respectively, of the rotary valve assembly. Although described with reference to
Via this disclosure, a pump disabler comprises a CHS 90 that can capture a movable component of the discharge valve assembly (e.g., a discharge valve poppet) and stop it from returning to the discharge valve seat. When the CHS 90 is activated, pulsating pressures can arise due to reciprocation of the reciprocating element 18 moving back and forth in the reciprocating element bore 24. As described hereinbelow, these pulsating pressures can be programmed to send a pulse in every stroke of the pump 10, or can be programmed, e.g., every fifth stroke, to create a desired pulse. As detailed further hereinbelow, the creation of pulsating flow rates of the discharged fluid (e.g., the fluid discharged via discharge outlet(s) 54 of pump 10) enabled by the CHS 90 of this disclosure can be utilized, for example, to improve fracture development. In embodiments, the CHS 90 can be activated or energized prior to positioning movable component (e.g., the poppet) of the discharge valve assembly 72 adjacent or within the valve arrestor thereof.
A discharge valve assembly 72 of this disclosure will now be described with reference to
As utilized with reference to components of discharge valve assembly 72 of
In the embodiment of
Discharge valve seat 72C is disposed within the pump fluid end body 8, such that, in operation, poppet 79 moves away from and toward discharge valve seat 72C, thus respectively opening and closing the discharge valve assembly 72 by removing contact of (e.g., valve body 72A of) poppet 79 with discharge valve seat 72C and providing contact of (e.g., valve body 72A of) poppet 79 with discharge valve seat 72C, respectively. The discharge valve assembly 72 comprises a biasing member, which, in the discharge valve assembly 72 of
Left side valve guide 73 and right side valve guide 74 of discharge valve assembly 72 maintain alignment of valve stem 103 comprising left side valve stem 103A and right side valve stem 103B within the pump fluid end 22. For example, left side valve guide 73 can help maintain alignment of left side valve stem 103A within the pump fluid end 22, while right side valve guide 74 can help maintain alignment of right side valve stem 103B within the pump fluid end 22. As noted above, discharge valve body 72A can be integrated as a single component with left side valve stem 103A and/or right side valve stem 103B. In such embodiments, valve stem 103 comprises left side 103A and right side 103B of the unitary valve stem 103, and left side valve guide 73 can help maintain alignment of the left side 103A of the valve stem 103 within the pump fluid end 22, while right side valve guide 74 can help maintain alignment of the right side 103B of the valve stem 103 within the pump fluid end 22.
As depicted in
As depicted in
As noted hereinabove, an electromagnetically actuatable CHS 90A can comprise a discharge valve arrestor 81, an electromagnet 97, and electrical wire(s) 98. Electromagnet 97 is positioned within valve arrestor 81, proximate the valve arrestor bore 81D of discharge valve arrestor 81. CHS 90A is operable as an electromagnetic locking system, whereby actuation of electromagnet 97 via the passage of electricity through electrical wires 98 magnetically attracts right side valve stem 103B when movement of poppet 79 in the direction of arrow A1 away from discharge valve seat 72C positions right side valve stem 103B within valve arrestor bore 81D. The magnetic attraction between electromagnet 97 and right side valve stem 103B results in locking of the right side valve stem 103B within valve arrestor 81, thus preventing closing of the discharge valve assembly 72 (i.e., preventing movement of poppet 79 back in the direction of arrow A2 toward discharge valve seat 72C).
The electromagnetically actuatable CHS 90A can be activated or energized prior to positioning of the poppet 79 (e.g., a portion of right side valve stem 103B of poppet 79) adjacent to or within valve arrestor bore 81D.
In alternative embodiments, the CHS 90 comprises a hydraulically actuatable CHS 90B. A discharge valve assembly 72 of this disclosure comprising such a hydraulically actuatable CHS 90B will now be described with reference to
Discharge valve arrestor 81 of
In operation, when hydraulically actuatable CHS 90B is not actuated, discharge valve assembly 72 can open as poppet 79 moves in the direction of arrow A1 and discharge valve body 72A is separated from discharge valve seat 72C, thus allowing fluid flow through discharge valve assembly 72 (i.e., between discharge valve body 72A and discharge valve seat 72C) and can close as poppet 79 moves in the direction of arrow A2 and discharge valve body 72A contacts discharge valve seat 72C, thus preventing fluid flow through discharge valve assembly 72 (i.e., between discharge valve body 72A and discharge valve seat 72C). In the embodiment of
The cylinder fluid 93 utilized to operate the piston 94 of the hydraulically actuatable CHS 90B can comprise a conventional hydraulic fluid. In such embodiments, cylinder piston-side port 95A can be fluidly connected with an external source of hydraulic fluid (e.g., external to a pump 10 comprising the discharge valve assembly 72), and cylinder rod-side port 95B can, as depicted in
The CHS 90 can be externally controllable, such that timing of the actuation thereof can be provided from a source external to the pump 10.
Also disclosed herein is a pump fluid end 22 comprising the discharge valve assembly 72 having the CHS 90 as described hereinabove. The pump fluid end 22 comprises: one or more chambers 28, each of the one or more chambers 28 having a fluid inlet 38 and a discharge outlet 54 and comprising: a reciprocating element 18 at least partially within a reciprocating element bore 24 of the pump fluid end 22, wherein the reciprocating element bore 24 extends into the pump fluid end 22 from a back end S2 of the pump fluid end 22 and has a central axis 17; a suction valve assembly 56 configured to control fluid flow into the chamber 28; and a discharge valve assembly 72 configured to control fluid flow out of the chamber 28, wherein at least one of the one or more chambers 28 comprises the discharge valve assembly 72 comprising a CHS 90 as described hereinabove.
The pump fluid end 22 of this disclosure can be a concentric bore pump fluid end, as described with reference to
Also disclosed herein is a pump 10 comprising a pump fluid end 22 of this disclosure comprising the discharge valve assembly 72 having the CHS 90 as described hereinabove; and a pump power end 12, wherein the pump power end 12 is operable to reciprocate the reciprocating element 18 within the reciprocating element bore 24 of the pump fluid end 22. The pump fluid end 22 of the pump 10 comprises one or more chambers 28, each of the one or more chambers 28 having a fluid inlet 38 and a discharge outlet 54 and comprising: a reciprocating element 18 at least partially within a reciprocating element bore 24 of the pump fluid end 22, wherein the reciprocating element bore 24 extends into the pump fluid end 22 from a back end S2 of the pump fluid end 22 and has a central axis 17; a suction valve assembly 56 configured to control fluid flow into the chamber 28; and a discharge valve assembly 72 configured to control fluid flow out of the chamber 28, wherein at least one of the one or more chambers 28 comprises the discharge valve assembly 72 of this disclosure comprising the CHS 90. As noted above, the pump fluid end 22 can be a concentric bore pump fluid end 22; or a cross-bore pump fluid end 22.
In embodiments, the pump 10 is a multiplex pump comprising a plurality of chambers 28, wherein the plurality comprises N chambers 28, and wherein the at least one of the one or more chambers 28 that comprises the CHS 90 comprises n of the N chambers, wherein n is from 1 to N. In embodiments, n=1, such that a single of the plurality of chambers 28 comprises a CHS 90 of this disclosure. In alternative embodiments, n=N, such that all of the plurality of chambers 28 comprise a CHS 90 of this disclosure.
A pump 10 of this disclosure can be a multiplex pump comprising a plurality (e.g., N) of reciprocating assemblies (e.g., reciprocating elements 18, and a corresponding plurality (e.g., N) of reciprocating element bores 24, suction valve assemblies 56, and discharge valve assemblies 72). The plurality (N) can comprise any number such as, for example, 2, 3, 4, 5, 6, 7, or more. For example, in embodiments, pump 10 is a triplex pump, wherein the plurality comprises three (e.g., N=3). In alternative embodiments, pump 10 comprises a Quintuplex pump, wherein the plurality comprises five (e.g., N=5). For example,
Also disclosed herein is a method of disabling a pump 10 and/or discharging fluid from the pump 10 such that the discharged fluid exhibits a pulsed flow rate. The method comprises: pumping a fluid with a pump 10 of this disclosure, and actuating the CHS 90 of one or more of the at least one of the one or more chambers 28 of the pump fluid end 22 comprising the CHS 90, whereby the discharge valve assembly 72 of the one or more of the at least one of the one or more chambers 28 comprising the CHS 90 is held in the open configuration.
The pump 10 is a pump 10 of this disclosure comprising a pump fluid end 22 and a pump power end 12: wherein the pump fluid end 22 comprises: one or more chambers 28, each of the one or more chambers 28 having a fluid inlet 38 and a discharge outlet 54 and comprising a reciprocating element 18; a suction valve assembly 56 configured to control fluid flow into the chamber 28; and a discharge valve assembly 72 configured to control fluid flow out of the chamber 28, wherein the reciprocating element 18 is at least partially within a reciprocating element bore 24 of the pump fluid end 24, wherein the reciprocating element bore 24 extends into the pump fluid end 22 from a back end S2 of the pump fluid end 22 and has a central axis 17; and wherein at least one of the one or more chambers 28 comprises a CHS 90 of this disclosure, wherein the CHS 90 is controllable to hold the discharge valve assembly 72 in an open configuration; and wherein the pump power end 12 is operable to reciprocate the reciprocating element 18 within the reciprocating element bore 24 of the pump fluid end 22.
In embodiments, each of the one or more chambers 28 comprises a CHS 90 of this disclosure, and the method comprises disabling the pump 10 by actuating the CHS 90 of each of the one or more chambers 28, whereby the discharge valve assemblies 72 of each of the one or more chambers 28 are held in the open configuration such that the pump 10 is disabled.
In embodiments, the actuating the CHS 90 of one or more of the at least one of the one or more chambers 28 comprising the CHS 90 results in at least one of the one or more chambers 28 of the pump fluid end 22 having a discharge valve assembly 72 that is not held in the open configuration, such that the fluid discharged from the pump 10 via the fluid outlet(s) 54 (e.g., the discharged fluid) exhibits a pulsed flow rate. The movement of the reciprocating element(s) 18 can thus cause a pressure fluctuation which can be utilized to help fracture initiations and extensions. For example, as depicted in
Also disclosed herein are a method of servicing a wellbore and a wellbore servicing system 200 comprising a pump of this disclosure. An embodiment of a wellbore servicing system 200 and a method of servicing a wellbore via the wellbore servicing system 200 will now be described with reference to
A method of servicing a wellbore 224 according to this disclosure comprises: fluidly coupling a pump 10 of this disclosure to a source of a wellbore servicing fluid and to the wellbore 224; and communicating wellbore servicing fluid into a formation 228 in fluid communication with the wellbore 224 via the pump 10, wherein the pump comprises a pump fluid end 22 and a pump power end 12, wherein the pump fluid end 22 comprises: one or more chambers 28, each of the one or more chambers 28 having a fluid inlet 38 and a discharge outlet 54 and comprising a reciprocating element 18; a suction valve assembly 56 configured to control fluid flow into the chamber 28; and a discharge valve assembly 72 configured to control fluid flow out of the chamber 28, wherein the reciprocating element 18 is at least partially within a reciprocating element bore 24 of the pump fluid end 22, wherein the reciprocating element bore 24 extends into the pump fluid end 22 from a back end S2 of the pump fluid end 22 and has a central axis 17; and wherein at least one of the one or more chambers 28 comprises a CHS 90 of this disclosure, wherein the CHS 90 is controllable to hold the discharge valve assembly 72 in an open configuration; and wherein the pump power end 12 is operable to reciprocate the reciprocating element 18 within the reciprocating element bore 24 of the pump fluid end 22.
The method of servicing the wellbore can further comprise: disabling the pump 10 and/or discharging fluid from the pump 10 such that the discharged fluid (e.g., the fluid discharged via the discharge outlet(s) 54) exhibits a pulsed flow rate by actuating the CHS 90 of one or more of the at least one of the one or more chambers 28 comprising the CHS 90, whereby the discharge valve assembly 72 of the one or more of the at least one of the one or more chambers 28 comprising the CHS 90 is held in the open configuration.
In embodiments, each of the one or more chambers 28 comprises a CHS 90 of this disclosure, and the method comprises disabling the pump 10 by actuating the CHS 90 of each of the one or more chambers 28, whereby the discharge valve assemblies 72 of each of the one or more chambers 28 are held in the open configuration such that the pump 10 is disabled.
In embodiments, the actuating of the CHS 90 of one or more of the at least one of the one or more chambers 28 comprising the CHS 90 results in at least one of the one or more chambers 28 of the pump fluid end 22 having a discharge valve assembly 72 that is not held in the open configuration, such that the discharged fluid exhibits a pulsed flow rate. The pulsed flow rate can be controlled to match a resonant frequency of the formation 228.
In embodiments, the method of servicing the wellbore comprises fluidly coupling a plurality of pumps 10 to the wellbore 224, communicating the wellbore servicing fluid into the formation 228 via a combined discharge of the plurality of pumps 10, discharging fluid from one or more of the plurality of pumps 10 such that the combined discharged fluid exhibits a pulsed flow rate by actuating the CHS 90 of one or more of the at least one of the one or more chambers 28 comprising the CHS 90 of the one or more of the plurality of pumps 10, whereby the discharge valve assembly 72 of the one or more of the at least one of the one or more chambers 28 comprising the CHS 90 of the one or more of the plurality of pumps 10 is held in the open configuration.
The pumping of the plurality of pumps 10 can be controlled such that the combined discharged fluid has a desired pressure modulation. In this manner, for example, a desired pressure modulation of the discharged fluid can be utilized to enhance fracturing of a formation 228. For example, the pressure modulation can be controlled to match a frequency modulation of the formation 228.
It will be appreciated that the wellbore servicing system 200 disclosed herein can be used for any purpose. In embodiments, the wellbore servicing system 200 may be used to service a wellbore 224 that penetrates a subterranean formation by pumping a wellbore servicing fluid into the wellbore and/or subterranean formation. As used herein, a “wellbore servicing fluid” or “servicing fluid” refers to a fluid used to drill, complete, work over, fracture, repair, or in any way prepare a well bore for the recovery of materials residing in a subterranean formation penetrated by the well bore. It is to be understood that “subterranean formation” encompasses both areas below exposed earth and areas below earth covered by water such as ocean or fresh water. Examples of servicing fluids suitable for use as the wellbore servicing fluid, the another wellbore servicing fluid, or both include, but are not limited to, cementitious fluids (e.g., cement slurries), drilling fluids or muds, spacer fluids, fracturing fluids or completion fluids, and gravel pack fluids, remedial fluids, perforating fluids, diverter fluids, sealants, drilling fluids, completion fluids, gelation fluids, polymeric fluids, aqueous fluids, oleaginous fluids, etc.
In embodiments, the wellbore servicing system 200 comprises one or more pumps 10 operable to perform oilfield and/or well servicing operations. Such operations may include, but are not limited to, drilling operations, fracturing operations, perforating operations, fluid loss operations, primary cementing operations, secondary or remedial cementing operations, or any combination of operations thereof. Although a wellbore servicing system is illustrated, skilled artisans will readily appreciate that the pump 10 disclosed herein may be employed in any suitable operation.
In embodiments, the wellbore servicing system 200 may be a system such as a fracturing spread for fracturing wells in a hydrocarbon-containing reservoir. In fracturing operations, wellbore servicing fluids, such as particle laden fluids, are pumped at high-pressure into a wellbore. The particle laden fluids may then be introduced into a portion of a subterranean formation at a sufficient pressure and velocity to cut a casing and/or create perforation tunnels and fractures within the subterranean formation. Proppants, such as grains of sand, are mixed with the wellbore servicing fluid to keep the fractures open so that hydrocarbons may be produced from the subterranean formation and flow into the wellbore. Hydraulic fracturing may desirably create high-conductivity fluid communication between the wellbore and the subterranean formation.
The wellbore servicing system 200 comprises a blender 202 that is coupled to a wellbore services manifold trailer 204 via flowline 206. As used herein, the term “wellbore services manifold trailer” includes a truck and/or trailer comprising one or more manifolds for receiving, organizing, and/or distributing wellbore servicing fluids during wellbore servicing operations. In this embodiment, the wellbore services manifold trailer 204 is coupled to six positive displacement pumps (e.g., such as pump 10 that may be mounted to a trailer and transported to the wellsite via a semi-tractor) via outlet flowlines 208 and inlet flowlines 210. In alternative embodiments, however, there may be more or less pumps used in a wellbore servicing operation. Outlet flowlines 208 are outlet lines from the wellbore services manifold trailer 204 that supply fluid to the pumps 10. Inlet flowlines 210 are inlet lines from the pumps 10 that supply fluid to the wellbore services manifold trailer 204.
The blender 202 mixes solid and fluid components to achieve a well-blended wellbore servicing fluid. As depicted, sand or proppant 212, water 214, and additives 216 are fed into the blender 202 via feedlines 218, 220, and 212, respectively. The water 214 may be potable, non-potable, untreated, partially treated, or treated water. In embodiments, the water 214 may be produced water that has been extracted from the wellbore while producing hydrocarbons form the wellbore. The produced water may comprise dissolved and/or entrained organic materials, salts, minerals, paraffins, aromatics, resins, asphaltenes, and/or other natural or synthetic constituents that are displaced from a hydrocarbon formation during the production of the hydrocarbons. In embodiments, the water 214 may be flowback water that has previously been introduced into the wellbore during wellbore servicing operation. The flowback water may comprise some hydrocarbons, gelling agents, friction reducers, surfactants and/or remnants of wellbore servicing fluids previously introduced into the wellbore during wellbore servicing operations.
The water 214 may further comprise local surface water contained in natural and/or manmade water features (such as ditches, ponds, rivers, lakes, oceans, etc.). Still further, the water 214 may comprise water stored in local or remote containers. The water 214 may be water that originated from near the wellbore and/or may be water that has been transported to an area near the wellbore from any distance. In some embodiments, the water 214 may comprise any combination of produced water, flowback water, local surface water, and/or container stored water. In some implementations, water may be substituted by nitrogen or carbon dioxide; some in a foaming condition.
In embodiments, the blender 202 may be an Advanced Dry Polymer (ADP) blender and the additives 216 are dry blended and dry fed into the blender 202. In alternative embodiments, however, additives may be pre-blended with water using other suitable blenders, such as, but not limited to, a GEL PRO blender, which is a commercially available preblender trailer from Halliburton Energy Services, Inc., to form a liquid gel concentrate that may be fed into the blender 202. The mixing conditions of the blender 202, including time period, agitation method, pressure, and temperature of the blender 202, may be chosen by one of ordinary skill in the art with the aid of this disclosure to produce a homogeneous blend having a desirable composition, density, and viscosity. In alternative embodiments, however, sand or proppant, water, and additives may be premixed and/or stored in a storage tank before entering a wellbore services manifold trailer 204.
In embodiments, the pump(s) 10 (e.g., pump(s) 10 and/or maintained pump(s) 10) pressurize the wellbore servicing fluid to a pressure suitable for delivery into a wellbore 224 or wellhead. For example, the pumps 10 may increase the pressure of the wellbore servicing fluid (e.g., the wellbore servicing fluid and/or the another wellbore servicing fluid) to a pressure of greater than or equal to about 3,000 psi, 5,000 psi, 10,000 psi, 20,000 psi, 30,000 psi, 40,000 psi, or 50,000 psi, or higher.
From the pumps 10, the wellbore servicing fluid may reenter the wellbore services manifold trailer 204 via inlet flowlines 210 and be combined so that the wellbore servicing fluid may have a total fluid flow rate that exits from the wellbore services manifold trailer 204 through flowline 226 to the flow connector wellbore 1128 of between about 1 BPM to about 200 BPM, alternatively from between about 50 BPM to about 150 BPM, alternatively about 100 BPM. In embodiments, each of one or more pumps 10 discharge wellbore servicing fluid at a fluid flow rate of between about 1 BPM to about 200 BPM, alternatively from between about 50 BPM to about 150 BPM, alternatively about 100 BPM. In embodiments, each of one or more pumps 10 discharge wellbore servicing fluid at a volumetric flow rate of greater than or equal to about 3, 10, or 20 barrels per minute (BPM), or in a range of from about 3 to about 20, from about 10 to about 20, or from about 5 to about 20 BPM.
Persons of ordinary skill in the art with the aid of this disclosure will appreciate that the flowlines described herein are piping that are connected together for example via flanges, collars, welds, etc. These flowlines may include various configurations of pipe tees, elbows, and the like. These flowlines connect together the various wellbore servicing fluid process equipment described herein.
Also disclosed herein are methods for servicing a wellbore (e.g., wellbore 224). Without limitation, servicing the wellbore may include: positioning the wellbore servicing composition in the wellbore 224 (e.g., via one or more pumps 10 as described herein) to isolate the subterranean formation from a portion of the wellbore; to support a conduit in the wellbore; to plug a void or crack in the conduit; to plug a void or crack in a cement sheath disposed in an annulus of the wellbore; to plug a perforation; to plug an opening between the cement sheath and the conduit; to prevent the loss of aqueous or nonaqueous drilling fluids into loss circulation zones such as a void, vugular zone, or fracture; to plug a well for abandonment purposes; to divert treatment fluids; and/or to seal an annulus between the wellbore and an expandable pipe or pipe string. In other embodiments, the wellbore servicing systems and methods may be employed in well completion operations such as primary and secondary cementing operation to isolate the subterranean formation from a different portion of the wellbore.
In embodiments, a wellbore servicing method may comprise transporting a positive displacement pump (e.g., pump 10) to a site for performing a servicing operation. Additionally or alternatively, one or more pumps may be situated on a suitable structural support. Non-limiting examples of a suitable structural support or supports include a trailer, truck, skid, barge or combinations thereof. In embodiments, a motor or other power source for a pump may be situated on a common structural support.
In embodiments, a wellbore servicing method may comprise providing a source for a wellbore servicing fluid. As described above, the wellbore servicing fluid may comprise any suitable fluid or combinations of fluid as may be appropriate based upon the servicing operation being performed. Non-limiting examples of suitable wellbore servicing fluid include a fracturing fluid (e.g., a particle laden fluid, as described herein), a perforating fluid, a cementitious fluid, a sealant, a remedial fluid, a drilling fluid (e.g., mud), a spacer fluid, a gelation fluid, a polymeric fluid, an aqueous fluid, an oleaginous fluid, an emulsion, various other wellbore servicing fluid as will be appreciated by one of skill in the art with the aid of this disclosure, and combinations thereof. The wellbore servicing fluid may be prepared on-site (e.g., via the operation of one or more blenders) or, alternatively, transported to the site of the servicing operation.
In embodiments, a wellbore servicing method may comprise fluidly coupling a pump 10 to the wellbore servicing fluid source. As such, wellbore servicing fluid may be drawn into and emitted from the pump 10. Additionally or alternatively, a portion of a wellbore servicing fluid placed in a wellbore 224 may be recycled, i.e., mixed with the water stream obtained from a water source and treated in fluid treatment system. Furthermore, a wellbore servicing method may comprise conveying the wellbore servicing fluid from its source to the wellbore via the operation of the pump 10 disclosed herein.
In alternative embodiments, the reciprocating apparatus may comprise a compressor. In embodiments, a compressor similar to the pump 10 may comprise at least one each of a cylinder, plunger, connecting rod, crankshaft, and housing, and may be coupled to a motor. In embodiments, such a compressor may be similar in form to a pump and may be configured to compress a compressible fluid (e.g., a gas) and thereby increase the pressure of the compressible fluid. For example, a compressor may be configured to direct the discharge therefrom to a chamber or vessel that collects the compressible fluid from the discharge of the compressor until a predetermined pressure is built up in the chamber. Generally, a pressure sensing device may be arranged and configured to monitor the pressure as it builds up in the chamber and to interact with the compressor when a predetermined pressure is reached. At that point, the compressor may either be shut off, or alternatively the discharge may be directed to another chamber for continued operation.
In embodiments, a reciprocating apparatus comprises an internal combustion engine, hereinafter referred to as an engine. Such engines are also well known, and typically include at least one each of a plunger, cylinder, connecting rod, and crankshaft. The arrangement of these components is substantially the same in an engine and a pump (e.g. pump 10). A reciprocating element 18 such as a plunger may be similarly arranged to move in reciprocating fashion within the cylinder. Skilled artisans will appreciate that operation of an engine may somewhat differ from that of a pump. In a pump, rotational power is generally applied to a crankshaft acting on the plunger via the connecting rod, whereas in an engine, rotational power generally results from a force (e.g., an internal combustion) exerted on or against the plunger, which acts against the crankshaft via the connecting rod.
For example, in a typical 4-stroke engine, arbitrarily beginning with the exhaust stroke, the plunger is fully extended during the exhaust stroke, (e.g., minimizing the internal volume of the cylinder). The plunger may then be retracted by inertia or other forces of the engine componentry during the intake stroke. As the plunger retracts within the cylinder, the internal volume of cylinder increases, creating a low pressure within the cylinder into which an air/fuel mixture is drawn. When the plunger is fully retracted within the cylinder, the intake stroke is complete, and the cylinder is substantially filled with the air/fuel mixture. As the crankshaft continues to rotate, the plunger may then be extended, during the compression stroke, into the cylinder compressing the air-fuel mixture within the cylinder to a higher pressure.
A spark plug may be provided to ignite the fuel at a predetermined point in the compression stroke. This ignition increases the temperature and pressure within the cylinder substantially and rapidly. In a diesel engine, however, the spark plug may be omitted, as the heat of compression derived from the high compression ratios associated with diesel engines suffices to provide spontaneous combustion of the air-fuel mixture. In either case, the heat and pressure act forcibly against the plunger and cause it to retract back into the cylinder during the power cycle at a substantial force, which may then be exerted on the connecting rod, and thereby on to the crankshaft.
Those of ordinary skill in the art will readily appreciate various benefits that may be realized by the present disclosure. The herein disclosed CHD 90 provides a way to disable a pump 10, or a section of a pump 10, using the discharge valve assembly 72. Such a design can be particularly useful for pumps 10 comprising a concentric pump fluid end 22, for which placement of a disabler mechanism at the suction side may not be possible.
The discharge valve assembly 72 of this disclosure comprising the CHS 90 can provide for pumping cessation on demand, and/or can provide for the production of desired pulsating pressures at different frequencies for production improvement.
The CHS 90 provides a powerful locking device that can be used to withstand the spring 31 force plus the cyclic forces created by the reciprocating fluid flow. When the CHS 90 is not actuated (e.g., fork 92 is retracted, electromagnet 97 is not energized), the poppet 79 can move freely back and forth along central axis 17A in the directions indicated by arrow A1 and A2, as a conventional discharge valve. When it is desired to disable the pump 10, CHS 90 is actuated, suction valve assembly 56 holds the discharge pressure, and fluid within pump chamber 28 will flow back and forth into the flow lines. The net flow of the pump 10 can therefore be stopped. The ability to disable a pump 10 as described herein can make the pump 10 suitable for electric drive systems, such that the pump 10 can be disabled when motor inertial energy cannot be mechanically decoupled from the pump 10.
Because the fluid flow can continue reciprocating after CHS 90 is actuated, not only can the pump 10 of this disclosure have a net-flow stopping system provided by the discharge valve assembly 72 comprising the CHS 90, the pump 10 can also be operated, as described hereinabove, to generate a (e.g., medium high frequency) pressure fluctuation (e.g., a cyclic pressure fluctuation) that can be utilized, for example, to ease fracture creation and extension.
The following are non-limiting, specific embodiments in accordance with the present disclosure:
In a first embodiment, a discharge valve assembly configured to control fluid flow out of a chamber of a pump fluid end of a pump comprises a controllable holding system (CHS), wherein the CHS is controllable to hold the discharge valve assembly in an open configuration.
A second embodiment can include the discharge valve assembly of the first embodiment, wherein the discharge valve assembly is a poppet-type valve assembly or a rotary-type valve assembly.
A third embodiment can include the discharge valve assembly of the first embodiment or the second embodiment, wherein the CHS is electromagnetically, hydraulically, and/or mechanically actuatable.
A fourth embodiment can include the discharge valve assembly of the third embodiment, wherein the CHS is electromagnetically actuatable.
A fifth embodiment can include the discharge valve assembly of the third embodiment, wherein the CHS is hydraulically actuatable, and wherein the CHS comprises a valve arrestor, a fork, a hydraulic cylinder, a hydraulic fluid, and a piston.
A sixth embodiment can include the discharge valve assembly of the fifth embodiment, wherein the fork, the hydraulic cylinder, the hydraulic fluid, and the piston are located primarily within the valve arrestor.
A seventh embodiment can include the discharge valve assembly of the fifth embodiment or the sixth embodiment, wherein the hydraulic fluid comprises a hydraulic fluid introduced from external the pump fluid end comprising the discharge valve assembly or a wellbore servicing fluid being pumped by the pump fluid end.
An eighth embodiment can include the discharge valve assembly of any one of the first to seventh embodiments, wherein the CHS is externally controllable.
In a ninth embodiment, a pump fluid end comprises: one or more chambers, each of the one or more chambers having a fluid inlet and a discharge outlet and comprising: a reciprocating element at least partially within a reciprocating element bore of the pump fluid end, wherein the reciprocating element bore extends into the pump fluid end from a back end of the pump fluid end and has a central axis; a suction valve assembly configured to control fluid flow into the chamber; and a discharge valve assembly configured to control fluid flow out of the chamber, wherein at least one of the one or more chambers comprises the discharge valve assembly of any one of the first to the eighth embodiments.
A tenth embodiment can include the pump fluid end of the ninth embodiment, wherein the pump fluid end is a concentric bore pump fluid end or a cross bore pump fluid end.
In an eleventh embodiment, a pump comprises the pump fluid end of the ninth embodiment or the tenth embodiment and a pump power end, wherein the pump power end is operable to reciprocate the reciprocating element within the reciprocating element bore of the pump fluid end.
A twelfth embodiment can include the pump of the eleventh embodiment, wherein the pump is a multiplex pump comprising a plurality of chambers, wherein the plurality comprises N chambers, and wherein the at least one of the one or more chambers that comprises the controllable holding system (CHS) comprises n of the N chambers, wherein n is from 1 to N.
A thirteenth embodiment can include the pump of the twelfth embodiment, wherein n=1, such that a single of the plurality of chambers comprises the CHS, or wherein n=N, such that all of the plurality of chambers comprise the CHS.
In a fourteenth embodiment, a method of disabling a pump and/or discharging fluid from the pump such that the discharged fluid exhibits a pulsed flow rate comprises: pumping a fluid with the pump, wherein the pump comprises a pump fluid end and a pump power end: wherein the pump fluid end comprises: one or more chambers, each of the one or more chambers having a fluid inlet and a discharge outlet and comprising a reciprocating element; a suction valve assembly configured to control fluid flow into the chamber; and a discharge valve assembly configured to control fluid flow out of the chamber, wherein the reciprocating element is at least partially within a reciprocating element bore of the pump fluid end, wherein the reciprocating element bore extends into the pump fluid end from a back end of the pump fluid end and has a central axis; and wherein at least one of the one or more chambers comprises a controllable holding system (CHS), wherein the CHS is controllable to hold the discharge valve assembly in an open configuration; and wherein the pump power end is operable to reciprocate the reciprocating element within the reciprocating element bore of the pump fluid end; and actuating the CHS of one or more of the at least one of the one or more chambers comprising the CHS, whereby the discharge valve assembly of the one or more of the at least one of the one or more chambers comprising the CHS is held in the open configuration.
A fifteenth embodiment can include the method of the fourteenth embodiment, wherein each of the one or more chambers comprises the CHS, and wherein the method comprises disabling the pump by actuating the CHS of each of the one or more chambers, whereby the discharge valve assemblies of each of the one or more chambers are held in the open configuration such that the pump is disabled.
A sixteenth embodiment can include the method of the fourteenth embodiment, wherein the actuating the CHS of one or more of the at least one of the one or more chambers comprising the CHS results in at least one of the one or more chambers of the pump fluid end having a discharge valve assembly that is not held in the open configuration, such that the discharged fluid exhibits a pulsed flow rate.
In a seventeenth embodiment, a method of servicing a wellbore comprises: fluidly coupling a pump to a source of a wellbore servicing fluid and to the wellbore; and communicating wellbore servicing fluid into a formation in fluid communication with the wellbore via the pump, wherein the pump comprises a pump fluid end and a pump power end, wherein the pump fluid end comprises: one or more chambers, each of the one or more chambers having a fluid inlet and a discharge outlet and comprising a reciprocating element; a suction valve assembly configured to control fluid flow into the chamber; and a discharge valve assembly configured to control fluid flow out of the chamber, wherein the reciprocating element is at least partially within a reciprocating element bore of the pump fluid end, wherein the reciprocating element bore extends into the pump fluid end from a back end of the pump fluid end and has a central axis; and wherein at least one of the one or more chambers comprises a controllable holding system (CHS), wherein the CHS is controllable to hold the discharge valve assembly in an open configuration; and wherein the pump power end is operable to reciprocate the reciprocating element within the reciprocating element bore of the pump fluid end.
An eighteenth embodiment can include the method of the seventeenth embodiment further comprising: disabling the pump and/or discharging fluid from the pump such that the discharged fluid exhibits a pulsed flow rate by actuating the CHS of one or more of the at least one of the one or more chambers comprising the CHS, whereby the discharge valve assembly of the one or more of the at least one of the one or more chambers comprising the CHS is held in the open configuration.
A nineteenth embodiment can include the method of the seventeenth embodiment or the eighteenth embodiment, wherein each of the one or more chambers comprises the CHS, and wherein the method comprises disabling the pump by actuating the CHS of each of the one or more chambers, whereby the discharge valve assemblies of each of the one or more chambers are held in the open configuration such that the pump is disabled.
A twentieth embodiment can include the method of the seventeenth embodiment or the eighteenth embodiment, wherein the actuating the CHS of one or more of the at least one of the one or more chambers comprising the CHS results in at least one of the one or more chambers of the pump fluid end having a discharge valve assembly that is not held in the open configuration, such that the discharged fluid exhibits a pulsed flow rate.
A twenty first embodiment can include the method of the twentieth embodiment, wherein the pulsed flow rate matches a resonant frequency of the formation.
A twenty second embodiment can include the method of the twentieth embodiment or the twenty first embodiment, wherein the method comprises fluidly coupling a plurality of pumps to the wellbore, communicating the wellbore servicing fluid into the formation via a combined discharge of the plurality of pumps, discharging fluid from one or more of the plurality of pumps such that the combined discharged fluid exhibits a pulsed flow rate by actuating the CHS of one or more of the at least one of the one or more chambers comprising the CHS of the one or more of the plurality of pumps, whereby the discharge valve assembly of the one or more of the at least one of the one or more chambers comprising the CHS of the one or more of the plurality of pumps is held in the open configuration.
A twenty third embodiment can include the method of the twenty second embodiment further comprising controlling the pumping of the plurality of pumps such that the combined discharged fluid has a desired pressure modulation.
A twenty fourth embodiment can include the method of any one of the seventeenth to twenty third embodiments, wherein the wellbore servicing fluid comprises a fracturing fluid, a cementitious fluid, a remedial fluid, a perforating fluid, a sealant, a drilling fluid, a spacer fluid, a completion fluid, a gravel pack fluid, a diverter fluid, a gelation fluid, a polymeric fluid, an aqueous fluid, an oleaginous fluid, or a combination thereof.
A twenty fifth embodiment can include the method of any one of the seventeenth to twenty fourth embodiments, wherein the pump operates during the pumping of the wellbore servicing fluid at a pressure of greater than or equal to about 3,000 psi, 5,000 psi, 10,000 psi, 20,000 psi, 30,000 psi, 40,000 psi, or 50,000 psi.
A twenty sixth embodiment can include the method of any one of the seventeenth to twenty fifth embodiments, wherein the pump operates during the pumping of the wellbore servicing fluid at a volumetric flow rate of greater than or equal to about 3, 10, or 20 barrels per minute (BPM), or in a range of from about 3 to about 20, from about 10 to about 20, or from about 5 to about 20 BPM.
While embodiments have been shown and described, modifications thereof can be made by one skilled in the art without departing from the spirit and teachings of this disclosure. The embodiments described herein are exemplary only, and are not intended to be limiting. Many variations and modifications of the embodiments disclosed herein are possible and are within the scope of this disclosure. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, Rl, and an upper limit, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=Rl+k*(Ru−Rl), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term “optionally” with respect to any element of a claim is intended to mean that the subject element is required, or alternatively, is not required. Both alternatives are intended to be within the scope of the claim. Use of broader terms such as comprises, includes, having, etc. should be understood to provide support for narrower terms such as consisting of, consisting essentially of, comprised substantially of, etc.
Accordingly, the scope of protection is not limited by the description set out above but is only limited by the claims which follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated into the specification as an embodiment of the present disclosure. Thus, the claims are a further description and are an addition to the embodiments of the present disclosure. The discussion of a reference herein is not an admission that it is prior art, especially any reference that may have a publication date after the priority date of this application. The disclosures of all patents, patent applications, and publications cited herein are hereby incorporated by reference, to the extent that they provide exemplary, procedural, or other details supplementary to those set forth herein.
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